Delek Logistics Partners (DKL) 10-K5 Mar 142013 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information Document (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 28, 2013	Feb. 21, 2014	Feb. 21, 2014	Feb. 21, 2014
	Dec. 31, 2013	Jun. 28, 2013	Common Units [Member]	Subordinated Units [Member]	General Partner [Member]
Entity Information [Line Items]	'	'	'	'	'
Entity Registrant Name	'Delek Logistics Partners, LP	'	'	'	'
Entity Central Index Key	'0001552797	'	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'	'
Entity Filer Category	'Accelerated Filer	'	'	'	'
Document Type	'10-K	'	'	'	'
Document Period End Date	31-Dec-13	'	'	'	'
Document Fiscal Year Focus	'2013	'	'	'	'
Document Fiscal Period Focus	'FY	'	'	'	'
Amendment Flag	'false	'	'	'	'
Common Stock, Shares, Outstanding	'	'	12,152,498	11,999,258	492,893
Entity Well-known Seasoned Issuer	'No	'	'	'	'
Entity Voluntary Filers	'No	'	'	'	'
Entity Current Reporting Status	'Yes	'	'	'	'
Entity Public Float	'	$302,530,188	'	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010	Dec. 31, 2009
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010	Dec. 31, 2009
Current assets:	'		'		'		'	'
Cash and cash equivalents	$924	[1]	$23,452	[1],[2]	$35	[1]	'	$0	[1]
Accounts receivable	28,976		27,725	[2]	'		'	'
Inventory	17,512		14,351	[2]	'		'	'
Deferred tax assets	12		14	[2]	'		'	'
Other current assets	341		169	[2]	'		'	'
Total current assets	47,765		65,711	[2]	'		'	'
Property, plant and equipment:	'		'		'		'	'
Property, plant and equipment	235,588		216,048	[2]	'		'	'
Less: accumulated depreciation	-36,306		-24,991	[2]	'		'	'
Property, plant and equipment, net	199,282		191,057	[2]	'		'	'
Goodwill	10,454		10,454	[2]	7,499		7,499	'
Intangible assets, net	12,258		12,430	[2]	'		'	'
Other non-current assets	5,045		3,664	[2]	'		'	'
Total assets	274,804	[3]	283,316	[2],[3]	223,159	[3]	'	'
Current liabilities:	'		'		'		'	'
Accounts payable	26,045		21,849	[2]	'		'	'
Accounts payable to related parties	1,513		10,148	[2]	'		'	'
Fuel and other taxes payable	5,700		4,650	[2]	'		'	'
Accrued expenses and other current liabilities	5,776		3,650	[2]	'		'	'
Total current liabilities	39,034		40,297	[2]	'		'	'
Non-current liabilities:	'		'		'		'	'
Revolving credit facility	164,800		90,000	[2]	'		'	'
Asset retirement obligations	2,993		3,177	[2]	2,990		'	'
Deferred tax liabilities	324		17	[2]	'		'	'
Other non-current liabilities	5,612		9,810	[2]	'		'	'
Total non-current liabilities	173,729		103,004	[2]	'		'	'
Equity:	'		'		'		'	'
Predecessor division equity	0		35,590	[2]	'		'	'
Common unitholders - public; 9,353,240 units issued and outstanding at December 31, 2013 (9,200,000 at December 31, 2012)	183,839		178,728	[2]	'		'	'
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2013 (2,799,258 at December 31, 2012)	-176,680		-127,129	[2]	'		'	'
Subordinated unitholders - Delek; 11,999,258 units issued and outstanding at December 31, 2013 (11,999,258 at December 31, 2012)	59,386		52,875	[2]	'		'	'
General partner - Delek; 492,893 units issued and outstanding at December 31, 2013 (489,766 at December 31, 2012)	-4,504		-49	[2]	'		'	'
Total equity	62,041		140,015	[2]	129,142		28,643	'
Total liabilities and equity	$274,804		$283,316	[2]	'		'	'

[1]	Adjusted to include the historical cash flows of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parentheticals)	Dec. 31, 2013	Dec. 31, 2012
Common unitholders- public, units issued	9,353,240	9,200,000
Common unitholders - public, units issued	2,799,258	2,799,258
Subordinated unitholders - Delek, units issued	11,999,258	11,999,258
General partner - Delek, units issued	492,893	489,766
Common unitholders- public, units oustanding	9,353,240	9,200,000
Common unitholders - Delek, units outstanding	2,799,258	2,799,258
Subordinated limited partner, Units Outstanding	11,999,258	11,999,258
General Partners' Capital Account, Units Outstanding	492,893	489,766

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, 2013		Dec. 31, 2012		Dec. 31, 2011
Net sales	$907,428	[1],[2]	$1,022,586	[1],[2]	$744,079	[1],[2]
Operating costs and expenses:	'		'		'
Cost of goods sold	811,364	[1],[2]	959,434	[1],[2]	700,505	[1],[2]
Operating expenses	30,302	[1],[2]	30,397	[1],[2]	19,467	[1],[2]
General and administrative expenses	6,856	[1],[2]	9,150	[1],[2]	6,483	[1],[2]
Depreciation and amortization	12,436	[1],[3]	10,120	[1],[3]	6,061	[1],[3]
Loss (gain) on asset disposals	166	[1],[2],[3]	9	[1],[2],[3]	-2	[1],[2],[3]
Total operating costs and expenses	861,124	[2]	1,009,110	[2]	732,514	[2]
Operating income	46,304	[1],[2]	13,476	[1],[2]	11,565	[1],[2]
Interest expense, net	4,570	[2]	2,682	[2]	2,011	[2]
Net income before income tax expense (benefit)	41,734	[2]	10,794	[2]	9,554	[2]
Income tax expense (benefit)	757	[2]	-14,024	[2]	5,363	[2]
Net income	40,977	[2],[3]	24,818	[2],[3]	4,191	[2],[3]
Less: (Loss) income attributable to Predecessors	-6,853	[2]	16,408		4,191	[2]
Net income attributable to partners	47,830	[2]	8,410	[2]	0	[2]
Comprehensive income attributable to partners	47,830	[2]	8,410	[2]	0	[2]
Less: General partner's interest in net income	957	[2]	168	[2]	'
Limited partners' interest in net income	$46,873	[2]	$8,242	[2]	'
Net income per limited partner unit:	'		'		'
Common units - (basic)	$1.95	[2]	$0.34	[2]	'
Common units - (diluted)	$1.93	[2]	$0.34	[2]	'
Subordinated units - Delek (basic and diluted)	$1.95	[2]	$0.34	[2]	'
Weighted average limited partner units outstanding:	'		'		'
Common units - (basic)	12,025,249	[2]	11,999,258	[2]	'
Common units - (diluted)	12,148,774	[2]	11,999,258	[2]	'
Subordinated units - Delek (basic and diluted)	11,999,258	[2]	11,999,258	[2]	'
Cash distributions per unit	$1.60	[2]	$0.22	[2]	'

[1]	The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[2]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical cash flows of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Consolidated_Statements_of_Par

Consolidated Statements of Partners' Equity (USD $)		Total		Predecessor [Member]	Common- Public [Member]	Common- Delek [Member]	Suborditnated- Delek [Member]	General Partner [Member]
Beginning balance at Dec. 31, 2010		$28,643,000		$28,643,000	$0	$0	$0	$0
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'		'	'	'	'	'
Non-cash contribution of Paline and Contributed Lion Oil Assets opening net assets from Delek		80,327,000		80,327,000	'	'	'	'
Sponsor contributions of equity to the Predecessor		15,897,000		15,897,000	'	'	'	'
Income (loss) attributable to Predecessors	[1]	4,191,000		4,191,000	'	'	'	'
Net income attributable to partners	[1]	0		'	'	'	'	'
Other		84,000		84,000	'	'	'	'
Ending balance at Dec. 31, 2011		129,142,000		129,142,000	0	0	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'		'	'	'	'	'
Contribution of equity to the Sponsor		-22,987,000		-22,987,000	'	'	'	'
Equity offering, net of issuance costs		175,459,000		0	175,459,000	0	0	0
Income (loss) attributable to Predecessors		16,408,000		16,408,000	'	'	'	'
Allocation of net assets contributed to the unitholders		0		-87,090,000	0	-11,554,000	48,753,000	49,891,000
Cash distributions		-166,535,000		0	0	-116,535,000	0	-50,000,000
Net income attributable to partners		8,410,000	[1]	0	3,160,000	960,000	4,122,000	168,000
Other		118,000		117,000	109,000	0	0	-108,000
Ending balance at Dec. 31, 2012		140,015,000	[2]	35,590,000	178,728,000	-127,129,000	52,875,000	-49,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'		'	'	'	'	'
Sponsor contributions of equity to the Predecessor		9,317,000		9,317,000	'	'	'	'
Income (loss) attributable to Predecessors		-6,853,000	[1]	-6,853,000	'	'	'	'
Liabilities not assumed by the Partnership		213,000		213,000	'	'	'	'
Allocation of net assets contributed to the unitholders		0		-38,267,000	0	37,502,000	0	765,000
Cash distributions	[3]	-129,564,000		0	-13,223,000	-96,848,000	-16,907,000	-2,586,000
Sponsorship contribution of fixed assets		520,000		0	0	510,000	0	10,000
Net income attributable to partners		47,830,000	[1]	0	18,035,000	5,455,000	23,383,000	957,000
Unit-based compensation		464,000		0	341,000	3,822,000	0	-3,699,000
Other		99,000		0	-42,000	8,000	35,000	98,000
Footnote [Abstract]		'		'	'	'	'	'
Decrease in equity balance due to acquisitions		56,500,000		'	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		200,000		'	'	'	'	'
Ending balance at Dec. 31, 2013		$62,041,000		$0	$183,839,000	($176,680,000)	$59,386,000	($4,504,000)

[1]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	Distributions to unitholders and general partner 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.

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net income	$40,977	[1],[2]	$24,818	[1],[2]	$4,191	[1],[2]
Adjustments to reconcile net income to net cash provided by operating activities:	'		'		'
Depreciation and amortization	12,436	[1],[3]	10,120	[1],[3]	6,061	[1],[3]
Amortization of unfavorable contract liability to revenue	-2,623	[1]	-668	[1]	0	[1]
Amortization of deferred financing costs	1,007	[1]	381	[1]	208	[1]
Accretion of asset retirement obligations	216	[1]	187	[1]	173	[1]
Loss (gain) on asset disposals	166	[1],[2],[3]	9	[1],[2],[3]	-2	[1],[2],[3]
Deferred income taxes	309	[1]	-18,762	[1]	-4,328	[1]
Unit-based compensation expense	464	[1]	1	[1]	0	[1]
Share-based compensation expense	0	[1]	92	[1]	64	[1]
Cash flows from investing activities:	'		'		'
Business combinations	-10,737	[1]	-23,272	[1]	0	[1]
Purchases of property, plant and equipment	-9,398	[1],[3],[4]	-26,759	[1],[3],[4]	-7,130	[1],[3],[4]
Proceeds from sale of property, plant and equipment	0	[1]	21	[1]	0	[1]
Net cash used in investing activities	-20,135	[1]	-50,010	[1]	-7,130	[1]
Cash flows from financing activities:	'		'		'
Proceeds from issuance of common units, net of underwriters' discount	0	[1]	179,676	[1]	0	[1]
Proceeds from issuance of additional units to maintain 2% General Partner interest	99	[1]	0	[1]	0	[1]
Distributions to general partner	-690	[1]	-50,000	[1]	0	[1]
Distributions to common unitholders - Public	-13,223	[1]	0	[1]	0	[1]
Distributions to common unitholders - Delek	-3,944	[1]	-116,535	[1]	0	[1]
Distributions to subordinated unitholders	-16,907	[1]	0	[1]	0	[1]
Distributions to Delek for contribution of Tyler Terminal and Tank Assets	-94,800	[1]	0	[1]	0	[1]
Proceeds from revolving credit facility	206,300	[1]	351,900	[1]	197,300	[1]
Payments of revolving credit facility	-131,500	[1]	-292,200	[1]	-196,000	[1]
Tax benefit from exercise of equity-based compensation	0	[1]	25	[1]	20	[1]
Offering costs	0	[1]	-4,217	[1]	0	[1]
Deferred financing costs paid	-2,273	[1]	-3,821	[1]	0	[1]
Predecessor division equity contribution (distribution)	9,317	[1]	-22,511	[1]	15,897	[1]
Reimbursement of capital expenditures by Sponsor	837	[1]	4,498	[1]	0	[1]
Net cash (used in) provided by financing activities	-46,784	[1]	46,815	[1]	17,217	[1]
Net (decrease) increase in cash and cash equivalents	-22,528	[1]	23,417	[1]	35	[1]
Cash and cash equivalents at the beginning of the period	23,452	[1],[5]	35	[1]	'
Cash and cash equivalents at the end of the period	924	[1]	23,452	[1],[5]	35	[1]
Cash paid during the period for:	'		'		'
Interest	3,242	[1]	2,006	[1]	1,807	[1]
Taxes	30	[1]	1,316	[1]	56	[1]
Non-cash financing activities:	'		'		'
Working capital retained by Sponsor	213	[1]	63,847	[1]	0	[1]
Sponsor contribution of fixed assets	520	[1]	476	[1]	0	[1]
Changes in assets and liabilities, net of acquisitions:	'		'		'
Accounts receivable	-1,251	[1]	-5,148	[1]	-2,628	[1]
Inventories and other current assets	-3,333	[1]	4,917	[1]	-10,705	[1]
Accounts payable and other current liabilities	7,402	[1]	-4,651	[1]	9,265	[1]
Accounts payable - related parties	-8,635	[1]	15,766	[1]	-12,252	[1]
Non-current assets and liabilities, net	-2,744	[1]	-450	[1]	-99	[1]
Net cash provided by (used in) operating activities	$44,391	[1]	$26,612	[1]	($10,052)	[1]

[1]	Adjusted to include the historical cash flows of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[4]	Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition
[5]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

General_Notes

General (Notes)	12 Months Ended
General (Notes)	Dec. 31, 2013
General [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	General
	Organization and Basis of Presentation
	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 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. The consolidated financial results for the year ended December 31, 2012 also include the results of operations for 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 through November 7, 2012. The balance sheet as of December 31, 2013 presents solely the consolidated financial position of the Partnership.
	The Partnership is a Delaware limited partnership formed in April 2012 by Delek and its subsidiary Delek Logistics GP, LLC, our general partner. On November 7, 2012, we completed our initial public offering (the "Offering") of 9,200,000 common units, representing limited partner interests.
	Upon completion of the Offering, the Partnership consisted of the assets, liabilities and results of operations of certain crude oil and refined product pipelines and transportation, wholesale marketing and terminalling assets previously operated or held by Delek and certain of its present subsidiaries including Delek Marketing & Supply, LLC ("Delek Marketing") and Lion Oil Company ("Lion Oil") and former subsidiaries including Paline Pipeline Company, LLC ("Paline"), which is now a subsidiary of the Partnership. Prior to the completion of the Offering, the assets, liabilities, and results of operations of the aforementioned assets related to the DKL Predecessor.
	On July 26, 2013, we acquired from Delek (i) the refined products terminal (the “Tyler Terminal”) located at Delek's Tyler, Texas Refinery (the "Tyler Refinery") and (ii) ninety-six 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”). The Tyler Acquisition was a transfer between entities under common control. Accordingly, the accompanying financial statements and related notes of the DKL Predecessor and the Partnership have been retrospectively adjusted to include the historical results of the Tyler Terminal and Tank Assets for all periods presented through July 26, 2013 (the "Tyler Predecessor"). We refer to the historical results of the DKL Predecessor and the Tyler Predecessor collectively as our "Predecessors." See Note 3 for further information regarding the Tyler Acquisition.
	Description of Business
	The Partnership owns and operates crude oil and refined products logistics and marketing assets. 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 Delek’s refineries in Tyler, Texas (the "Tyler Refinery") and El Dorado, Arkansas (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, 2013
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.
	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. As of December 31, 2013 and 2012, any cash equivalents consisted primarily of overnight investments in U.S. Government obligations, bank repurchase obligations collateralized by U.S. Government obligations and bank money market accounts.
	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, 2013 and 2012.
	Two customers accounted for approximately 27.2% and 18.9% of the consolidated accounts receivable balance as of December 31, 2013 and 2012, respectively.
	Inventory
	Inventory consists of refined products, which are stated at the lower of cost or market on a FIFO basis.
	Two vendors in the wholesale marketing and terminalling segment accounted for a total of 96.1%, 76.1% and 96.8% of our consolidated inventory purchases during the years ended December 31, 2013, 2012 and 2011, 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 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, 2013, 2012, or 2011.
	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 hedging 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 monthly basis, utilizing valuations from third party financial and brokerage institutions. During the years ended December 31, 2013, 2012, and 2011, we did not elect to apply hedging treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of operations.
	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 the cash collateral arising from these derivative positions.
	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 statement of position 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, 2013 or 2012, 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, 2013 and 2012 is as follows (in thousands):


			December 31,
			2013			2012
	Beginning balance		$	3,177		$	2,990

	Liabilities settled		(400		)	—

	Accretion expense		216			187

	Ending balance		$	2,993		$	3,177


	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.
	Other Non-current Liabilities
	We recognized in 2011 an estimated $6.0 million liability associated with a customer contract in our December 2011 acquisition of Paline. We amortized approximately $2.6 million to revenue during 2013. No amounts were remaining in other non-current liabilities as of December 31, 2013. The amount to amortize in 2014 is included in other current liabilities. We assumed in 2011 an estimated $2.9 million of non-current tank and pipeline inspection liabilities in the Lion Oil Acquisition, of which $0.8 million was outstanding as of December 31, 2013. During the fourth quarter of 2012, we recognized a liability of $4.5 million related to Delek's reimbursement of maintenance capital associated with three existing capital projects per the Omnibus Agreement (as defined below in Note 18—Related Party Transactions). This liability will be amortized to revenue over the estimated lives of the assets once placed in service. The outstanding liability as of December 31, 2013 was $4.3 million.
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, 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, 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 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 financial statements.
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 Tyler Predecessor, totaled $0.5 million, $0.5 million, and $0.3 million for the years ended December 31, 2013, 2012, and 2011, 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 his, her or its share of items of income, gain, loss and deduction in computing his, her or 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 the 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 $0.8 million in 2013. 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.
Comprehensive Income
Comprehensive income for the years ended December 31, 2013, 2012, and 2011 was equivalent to net income.
New Accounting Pronouncements
In July 2012, the FASB issued guidance regarding testing indefinite-lived intangible assets for impairment that gives companies the option to perform a qualitative assessment before calculating the fair value of the indefinite-lived intangible asset. Under the guidance, if this option is selected, a company is not required to calculate the fair value of the indefinite-lived intangible unless the entity determines it is more likely than not that its fair value is less than its carrying amount. In October 2012, the FASB issued guidance regarding the application of the qualitative assessment permitted under the Accounting Standards Update 2012-02, issued in July. The guidance requires companies to focus on the significant inputs used to determine the fair value of indefinite-lived intangible assets when companies opt to perform the qualitative assessment. Companies must then evaluate the impact of certain events and circumstances that could have affected those inputs and weigh the identified factors prior to concluding whether the asset is impaired. As significant judgment is applied to conclude that an indefinite-lived intangible asset is not impaired based on a qualitative assessment, the analyses performed by the Company should be supported by clear documentation of the factors considered, including any necessary quantitative calculations. The guidance is effective for interim and annual reporting periods beginning January 1, 2013, but early adoption is permitted. The adoption of this guidance did not affect our business, financial position or results of operations.
In December 2011, the FASB issued guidance requiring the disclosure of information about offsetting and related arrangements to enable users of financial statements to understand the effect of these arrangements on financial position. The guidance requires the disclosure of both gross information and net information about both instruments and transactions eligible for offset in the balance sheet and instruments and transactions subject to an agreement similar to a master netting arrangement. In January 2013, the FASB issued an update limiting the scope of the offsetting disclosure requirements established by the original guidance, to certain derivatives (including bifurcated embedded derivatives), repurchase agreements and reverse repurchase agreements, and securities lending and securities borrowing transactions that are eligible for offset on the balance sheet or are subject to an agreement similar to a master netting arrangement, irrespective of whether they are offset on the balance sheet. This update amends the guidance that required companies to apply the requirements to all recognized financial instruments. The original and updated guidance is effective for interim and annual reporting periods beginning January 1, 2013 and retrospectively for all periods presented on the balance sheet. The adoption of this guidance did not affect our business, financial position or results of operations, but resulted in additional disclosures (see Note 14).

Acquisitions_Notes

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2013
Acquisitions [Abstract]	'
Acquisitions	'
	Acquisitions

	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"). We acquired the North Little Rock Terminal to expand our customer base and diversify our product mix. The aggregate purchase price was approximately $5.0 million. The allocation of the purchase price was based primarily upon a preliminary valuation. The preliminary valuation is subject to change during the purchase price allocation period.
	The preliminary allocation of the aggregate purchase price of the North Little Rock Terminal as of December 31, 2013 is summarized as follows (in thousands):


	Property, plant and equipment	$	4,987

	Intangible assets	13

	Total	$	5,000

	Pro Forma Financial Information - North Little Rock Acquisition
	We began consolidating the results of operations of the North Little Rock Terminal on October 24, 2013. The North Little Rock Terminal contributed $0.2 million and $0.1 million to net sales and net income, respectively, for the year ended December 31, 2013. Below are the unaudited pro forma consolidated results of operations for the years ended December 31, 2013 and 2012, as if these acquisitions had occurred on January 1, 2012 (in thousands):


			Year Ended December 31,
			2013				2012
	Net sales		$	908,867			$	1,024,025

	Net income		$	42,268			$	26,109


	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 barrels per day ("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 (i) entered into an asset purchase agreement, (ii) entered into the First Omnibus Amendment (as defined below in Note 18—Related Party Transactions, (iii) entered into a throughput and tankage agreement with respect to the Tyler Terminal and Tank Assets, (iv) entered into a lease and access agreement and (v) entered into a site services agreement. See Note 18 for additional information regarding these agreements.
	Tyler Terminal and Tank Assets Financial Results
	The acquisition of the Tyler Terminal and Tank Assets was considered a transfer of a business between entities under common control. Accordingly, the Tyler Acquisition was recorded at amounts based on the historical carrying value of the Tyler Terminal and Tank Assets as of July 26, 2013, which was $38.3 million. Our historical financial statements have been retrospectively adjusted to reflect the results of operations, financial position, cash flows and equity attributable to the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented. The results of the Tyler Terminal and the Tyler Tank Assets are included in the wholesale marketing and terminalling segment and the pipelines and transportation segment, respectively.
	The results of the Tyler Terminal and Tank Assets operations prior to the completion of the Tyler Acquisition on July 26, 2013 have been included in the Tyler Predecessor results in the tables below. The results of the Tyler Terminal and Tank Assets subsequent to July 26, 2013 have been included in the Partnership's results. Accordingly, for the year ended December 31, 2013, total operating revenues of $7.5 million and net income attributable to the Partnership of $3.9 million associated with the Tyler Terminal and Tank Assets are included in the combined consolidated statements of operations of the Partnership. Costs associated with the Tyler Acquisition in the amount of $0.3 million are included in general and administrative expenses for the year ended December 31, 2013.
	The tables on the following page present our results of operations, the effect of including the results of the Tyler Terminal and Tank Assets and the adjusted total amounts included in our combined consolidated financial statements.
	Combined Consolidated Balance Sheet as of December 31, 2012


			Delek Logistics				Tyler Terminal and Tank Assets				Delek Logistics Partners, LP
			Partners, LP				(Tyler Predecessor)				31-Dec-12
							(In thousands)
	ASSETS
	Current Assets:
	Cash and cash equivalents		$	23,452			$	—			$	23,452

	Accounts receivable		27,725				—				27,725

	Inventory		14,351				—				14,351

	Deferred tax assets		14				—				14

	Other current assets		169				—				169

	Total current assets		65,711				—				65,711

	Property, plant and equipment:
	Property, plant and equipment		172,300				43,748				216,048

	Less: accumulated depreciation		(18,790		)		(6,201		)		(24,991		)
	Property, plant and equipment, net		153,510				37,547				191,057

Goodwill		10,454				—				10,454

Intangible assets, net		12,430				—				12,430

Other non-current assets		3,664				—				3,664

Total assets		$	245,769			$	37,547			$	283,316

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable		$	21,849			$	—			$	21,849

Accounts payable to related parties		10,148				—				10,148

Fuel and other taxes payable		4,650				—				4,650

Accrued expenses and other current liabilities		3,615				35				3,650

Total current liabilities		40,262				35				40,297

Non-current liabilities:
Revolving credit facility		90,000				—				90,000

Asset retirement obligations		1,440				1,737				3,177

Deferred tax liability		17				—				17

Other non-current liabilities		9,625				185				9,810

Total non-current liabilities		101,082				1,922				103,004

Equity:
Predecessors division equity		—				35,590				35,590

Common unitholders - public (9,200,000 units issued and outstanding)		178,728				—				178,728

Common unitholders - Delek (2,799,258 units issued and outstanding)		(127,129		)		—				(127,129		)

Subordinated unitholders - Delek (11,999,258 units issued and outstanding)		52,875				—				52,875

General Partner unitholders - Delek (489,766 units issued and outstanding)		(49		)		—				(49		)

Total equity		104,425				35,590				140,015

Total liabilities and equity		$	245,769			$	37,547			$	283,316


Combined Consolidated Statements of Income


		Delek Logistics				Tyler Terminal and Tank Assets				Year Ended
		Partners, LP				(Tyler Predecessor)				December 31, 2013
						(In thousands)
Net Sales		$	907,428			$	—			$	907,428

Operating costs and expenses:
Cost of goods sold		811,364				—				811,364

Operating expenses		25,801				4,501				30,302

General and administrative expenses		6,254				602				6,856

Depreciation and amortization		10,686				1,750				12,436

Loss on asset disposals		166				—				166

Total operating costs and expenses		854,271				6,853				861,124

Operating income (loss)		53,157				(6,853		)		46,304

Interest expense, net		4,570				—				4,570

Net income (loss) before income tax expense		48,587				(6,853		)		41,734

Income tax expense		757				—				757

Net income (loss)		47,830				(6,853		)		40,977

Less: (Loss) attributable to Predecessors		—				(6,853		)		(6,853		)

Net income attributable to partners		$	47,830			$	—			$	47,830




						Tyler Terminal and				Year Ended
		Delek Logistics				Tank Assets				December 31, 2012
		Partners, LP				(Tyler Predecessor)				(Predecessors)
						(In thousands)
Net Sales		$	1,022,586			$	—			$	1,022,586

Operating costs and expenses:
Cost of goods sold		959,434				—				959,434

Operating expenses		23,362				7,035				30,397

General and administrative expenses		8,389				761				9,150

Depreciation and amortization		8,675				1,445				10,120

Loss on asset disposals		9				—				9

Total operating costs and expenses		999,869				9,241				1,009,110

Operating income (loss)		22,717				(9,241		)		13,476

Interest expense, net		2,682				—				2,682

Net income (loss) before income tax expense		20,035				(9,241		)		10,794

Income tax benefit		(14,024		)		—				(14,024		)

Net income (loss)		34,059				(9,241		)		24,818

Less: Income (loss) attributable to Predecessors		25,649				(9,241		)		16,408

Net income attributable to partners		$	8,410			$	—			$	8,410



		Delek Logistics				Tyler Terminal and				Year Ended
		Partners, LP				Tank Assets				December 31, 2011
		(DKL Predecessor)				(Tyler Predecessor)				(Predecessors)
						(In thousands)
Net Sales		$	744,079			$	—			$	744,079

Operating costs and expenses:
Cost of goods sold		700,505				—				700,505

Operating expenses		12,940				6,527				19,467

General and administrative expenses		5,795				688				6,483

Depreciation and amortization		4,820				1,241				6,061

Gain on disposal of assets		(2		)		—				(2		)

Total operating costs and expenses		724,058				8,456				732,514

Operating income (loss)		20,021				(8,456		)		11,565

Interest expense, net		2,011				—				2,011

Income (loss) before income tax expense		18,010				(8,456		)		9,554

Income tax expense		5,363				—				5,363

Net income (loss)		12,647				(8,456		)		4,191

Less: (Loss) income attributable to Predecessors		12,647				(8,456		)		4,191

Net income attributable to partners		$	—			$	—			$	—

Hopewell Acquisition
On July 19, 2013, the Partnership purchased from Enterprise TE Products Pipeline Company LLC a 13.5 mile pipeline (the "Hopewell Pipeline") that originates at the Tyler Refinery and terminates at the Hopewell Station, where it effectively connects to the Big Sandy Pipeline. 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").
The aggregate purchase price was approximately $5.7 million. The allocation of the purchase price was based primarily upon a preliminary valuation. During 2013, we adjusted certain of the acquisition-date fair values previously disclosed, based primarily on an analysis of intangible assets. The preliminary valuation is subject to change during the purchase price allocation period.
The preliminary allocation of the aggregate purchase price of the Hopewell Pipeline as of December 31, 2013 is summarized as follows (in thousands):


Property, plant and equipment	$	4,836

Intangible assets	864

Total	$	5,700

Amended and Restated Services Agreement (Big Sandy Terminal and Pipeline). In connection with the acquisition of the Hopewell Pipeline, on July 25, 2013, the Partnership and Delek entered into the Amended and Restated Services Agreement (Big Sandy Terminal and Pipeline), which amended and restated the Terminalling Services Agreement dated November 7, 2012 for the Big Sandy Terminal to include, among other things, a minimum throughput commitment and a per barrel throughput fee that Delek will pay us for throughput along the Tyler-Big Sandy Pipeline. See Note 18 for additional information on this agreement.
Pro Forma Financial Information - Hopewell Acquisition
We began consolidating the results of operations of the Hopewell Pipeline on July 19, 2013. Although the Hopewell Pipeline has not been operational since prior to January 1, 2012 due to required maintenance to return it to service, Delek paid to us pipeline fees for the Hopewell Pipeline during the year ended December 31, 2013. The Hopewell Pipeline contributed $0.4 million to net sales and a net loss of $0.5 million for the year ended December 31, 2013. The maintenance required to return the Hopewell Pipeline to service and thereby connect it to the Big Sandy Pipeline was completed in the fourth quarter 2013.
Below are the unaudited pro forma consolidated results of operations for the years ended December 31, 2013 and 2012, as if these acquisitions had occurred on January 1, 2012 (in thousands):


		Year Ended December 31,
		2013				2012
Net sales		$	908,382			$	1,023,540

Net income		$	41,291			$	25,132


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"). The aggregate purchase price was approximately $11.0 million. Big Sandy has previously been supplied by the Tyler Refinery but has been idle since November 2008. Big Sandy was contributed to the Partnership as part of the Offering.
The allocation of the aggregate purchase price of Big Sandy as of December 31, 2013 is summarized as follows (in thousands):


Property, plant and equipment	$	8,258

Intangible assets	1,229

Goodwill (all expected to be deductible for tax purposes)	1,540

Total	$	11,027


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 purchase price was approximately $12.3 million. 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. During the year ended December 31, 2013, more than half of the crude oil processed at the Tyler Refinery was supplied through the Nettleton Pipeline. The remainder of the crude oil was supplied through the McMurrey Pipeline, which also begins at our tank farms in and around Nettleton, Texas and then runs roughly parallel to the Nettleton Pipeline. Prior to the acquisition of the Nettleton Pipeline, Delek leased the Nettleton Pipeline from Plains under the terms of the Pipeline Capacity Lease Agreement dated April 12, 1999, as amended (the “Plains Lease”). The Plains Lease was terminated in connection with the acquisition of the Nettleton Pipeline. The Nettleton Pipeline was contributed to the Partnership as part of the Offering.
The allocation of the aggregate purchase price of the Nettleton Pipeline as of December 31, 2013 is summarized as follows (in thousands):


Property, plant and equipment	$	8,590

Intangible assets	2,240

Goodwill (all expected to be deductible for tax purposes)	1,415

Total	$	12,245



Pro Forma Financial Information - Nettleton and the Big Sandy Terminal
We began consolidating the results of operations of the Nettleton Pipeline and Big Sandy on January 31, 2012 and February 7, 2012, respectively. The Nettleton Pipeline contributed $9.0 million and $7.2 million to net sales and net income, respectively, for the year ended December 31, 2013. Big Sandy contributed $1.5 million and $1.2 million to sales and net income, respectively, for the year ended December 31, 2013. Below are the pro forma consolidated results of operations of the Predecessor for the year ended December 31, 2012, as if these acquisitions had occurred on January 1, 2012 (amounts in thousands):


		Year Ended December 31,
		2012
Net sales		$	1,022,715

Net income		$	24,941

Net_Income_Per_Unit_Notes

Net Income Per Unit (Notes)	12 Months Ended
	Dec. 31, 2013
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 security. 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 the general partner’s 2% interest and incentive distributions, if any, 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 distributions, if any, 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. The basic weighted-average number of units outstanding for the year ended December 31, 2013 increased to 24,514,527 units from 24,503,469 units in the third quarter 2013.
	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 are declared subsequent to quarter end. Therefore, the table 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,
		2013		2012
	Net income attributable to partners	$	47,830	$	8,410

	Less: General partner's distribution	785		110

	Less: Limited partners' distribution	19,292		2,688

	Less: Subordinated partner's distribution	19,199		2,688

	Earnings in excess of distributions	$	8,554	$	2,924


	General partner's earnings:
	Distributions	$	785	$	110

	Allocation of earnings in excess of distributions	172		58

	Total general partner's earnings	$	957	$	168


	Limited partners' earnings on common units:
	Distributions	$	19,292	$	2,688

	Allocation of earnings in excess of distributions	4,198		1,433

	Total limited partners' earnings on common units	$	23,490	$	4,121


	Limited partners' earnings on subordinated units:
	Distributions	$	19,199	$	2,688

	Allocation of earnings in excess of distributions	4,184		1,433

	Total limited partner's earnings on subordinated units	$	23,383	$	4,121


	Weighted average limited partner units outstanding:
	Common units - (basic)	12,025,249		11,999,258

	Common units - (diluted)	12,148,774		11,999,258

	Subordinated units - Delek (basic and diluted)	11,999,258		11,999,258


	Net income per limited partner unit:
	Common - (basic)	$	1.95	$	0.34

	Common - (diluted)	$	1.93	$	0.34

	Subordinated - (basic and diluted)	$	1.95	$	0.34

Major_Customer_Notes

Major Customer (Notes)	12 Months Ended
Major Customer (Notes)	Dec. 31, 2013
Major Customer [Abstract]	'
Major Customers, Policy [Policy Text Block]	'
	Major Customers
	One customer, Susser Petroleum Company ("Susser"), accounted for more than 10% of consolidated net sales for the year ended December 31, 2013. The amount of revenues from Susser during the year ended December 31, 2013 were $160.8 million, which represented 17.7% of our total consolidated net sales and 19.0% of our total net sales in our wholesale marketing and terminalling segment. Delek accounted for 84.2% of our total net sales in our pipelines and transportation segment during the year ended December 31, 2013.
	Two customers accounted for more than 10% of consolidated net sales for the years ended December 31, 2012 and 2011. During the year ended December 31, 2012, Delek accounted for 20.9% and Susser accounted for 17.5% of our total revenues, respectively, in our wholesale marketing and terminalling segment. Delek accounted for 88.7% our our revenues in our pipelines and transportation segment during the year ended December 31, 2012. The amount of revenues from Susser were $178.9 million and $154.6 million for the years ended December 31, 2012 and 2011 respectively, and are included in our wholesale marketing and terminalling segment. The amount of revenues from Delek were $236.7 million and $27.8 million for the years ended December 31, 2012 and 2011, respectively.
	We believe that gross margin is a better measure of performance of our business than revenue, particularly in our wholesale marketing and terminalling segment, as total revenue varies with the price of the underlying product, such as a gallon of finished product. Accordingly, we believe that, for the purpose of evaluating our business on a customer-specific basis, gross margin, which we define as net sales less cost of goods sold, is a more accurate indicator to reflect the importance of certain customers to our operations.
	Delek accounted for 72.2% and 84.0% of our gross margin in our wholesale marketing and terminalling segment and our pipelines and transportation segment, respectively, in the year ended December 31, 2013. Delek accounted for 51.2% and 57.3% of our Predecessor's gross margin in our wholesale and terminalling segment in the years ended December 31, 2012 and 2011, respectively, and for 88.7% and 46.0% of our gross margin in our pipelines and transportation segment, in the years ended December 31, 2012 and 2011, respectively.

Inventory_Notes

Inventory (Notes)	12 Months Ended
Inventory (Notes)	Dec. 31, 2013
Inventory, Net [Abstract]	'
Inventory	'
	Inventory
	Inventory consists of refined products which are stated at the lower of cost or market on a first-in, first-out ("FIFO") basis. Carrying value of inventories consisted of $17.5 million and $14.4 million of refined petroleum products as of December 31, 2013 and December 31, 2012, respectively.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2013
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,
		2013			2012

	Land and land improvements	$	1,931		$	1,084

	Building and building improvements	944			923

	Pipelines and terminals	205,866			175,456

	Asset retirement obligations	1,999			1,998

	Other equipment	2,219			1,557

	Construction in process	22,629			35,030

		235,588			216,048

	Less: accumulated depreciation	(36,306		)	(24,991		)
		$	199,282		$	191,057


	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2013 and 2012 are as follows (in thousands):


		As of and For the Year Ended December 31, 2013
		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment	$	174,823		$	60,765		$	235,588

	Less: Accumulated depreciation	(22,032		)	(14,274		)	(36,306		)
	Property, plant and equipment, net	$	152,791		$	46,491		$	199,282

	Depreciation expense	$	8,756		$	2,617		$	11,373





		As of and For the Year Ended December 31, 2012
		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment	$	168,196		$	47,852		$	216,048

	Less: Accumulated depreciation	(13,642		)	(11,349		)	(24,991		)
	Property, plant and equipment, net	$	154,554		$	36,503		$	191,057

	Depreciation expense	$	6,771		$	2,285		$	9,056

Goodwill_Notes

Goodwill (Notes)	12 Months Ended
	Dec. 31, 2013
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 in connection with the Offering and to the allocation of the purchase price of our Nettleton and Big Sandy acquisitions that occurred in 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 2013, 2012 and 2011. 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 2013, 2012 and 2011 the annual impairment review resulted in the determination that no impairment of goodwill had occurred. Goodwill was $10.5 million at December 31, 2013.

	A summary of our goodwill accounts is as follows (in thousands):



	Balance,	December 31, 2010	$	7,499

	Goodwill impairment		—

	Balance,	December 31, 2011	7,499

	Goodwill impairment		—

	Goodwill acquired through the business combinations of Nettleton and Big Sandy		2,955

	Balance,	December 31, 2012	10,454

	Goodwill impairment		—

	Balance,	December 31, 2013	$	10,454

Other_Intangibles_Notes

Other Intangibles (Notes)	12 Months Ended
	Dec. 31, 2013
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, 2013	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts	11.5	$	12,227	$	(7,885	)	$	4,342

	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	7,916		—			7,916

	Total		$	20,143	$	(7,885	)	$	12,258




		Useful			Accumulated
	As of December 31, 2012	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts	11.5	$	12,227	$	(6,822	)	$	5,405

	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	7,025		—			7,025

	Total		$	19,252	$	(6,822	)	$	12,430


	Amortization of intangible assets was $1.1 million, during each of the years ended December 31, 2013, 2012 and 2011 and is included in depreciation and amortization on the accompanying consolidated statements of operations. Amortization expense is estimated to be $1.1 million per year for the years ended 2014 through 2017.

LongTerm_Obligations_and_Short

Long-Term Obligations and Short-Term Note Payable (Notes)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	Long-Term Obligations
	Amended and Restated Credit Agreement
	On July 9, 2013, we amended and restated our senior secured revolving credit agreement, which we originally entered into on November 7, 2012, with Fifth Third Bank, as administrative agent, and a syndicate of lenders, (the "Amended and Restated Credit Agreement"). Under the terms of the Amended and Restated Credit Agreement, the lender commitments were increased from $175.0 million to $400.0 million and a dual currency borrowing tranche was added that permits draw downs in U.S. or Canadian dollars. The 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 $450.0 million, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. The Amended and Restated Credit Agreement matures on November 7, 2017.
	Borrowings denominated in U.S. dollars under the Amended and Restated Credit Agreement 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 under the Amended and Restated Credit Agreement bear interest at either a Canadian dollar prime rate, plus an applicable margin, or 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 recently reported leverage ratio. At December 31, 2013, the weighted average interest rate was approximately 2.5%. Additionally, the Amended and Restated Credit Facility requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of December 31, 2013, this fee was 0.40% per year.
	The obligations under the Amended and Restated Credit Agreement are secured by first priority liens on substantially all of the Partnership's and its U.S. subsidiaries' tangible and intangible assets. Additionally, Delek Marketing provides a limited guaranty of the Partnership's obligations under the 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 Amended and Restated Credit Agreement. As of December 31, 2013, the principal amount of the Holdings Note was $102.0 million, plus unpaid interest accrued since the issuance date.
	As of December 31, 2013, we had $164.8 million outstanding borrowings under the Amended and Restated Credit Agreement. Additionally, we had in place letters of credit totaling $12.0 million with Fifth Third bank, primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn by beneficiaries of these letters of credit at December 31, 2013. Amounts available under the Amended and Restated Credit Agreement as of December 31, 2013 were approximately $223.2 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, 2013 (in thousands):


		2014	2015	2016	2017		2018	Thereafter	Total
	Amended and Restated Credit Agreement	—	—	—	$	164,800	—	—	$	164,800

Equity_Notes

Equity (Notes)	12 Months Ended
Equity (Notes)	Dec. 31, 2013
Equity [Abstract]	'
Stockholders' Equity Note Disclosure [Text Block]	'
	Equity
	We had 9,353,240 common limited partner units held by the public outstanding as of December 31, 2013. Additionally, as of December 31, 2013, Delek owned a 60.0% 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 96.6% interest in our general partner, which owns the entire 2.0% general partner interest consisting of 492,893 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, 2013 (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
	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
	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
	GP units issued to maintain 2% interest		—			—			—		3,127	3,127
	Unit-based compensation awards (1)		153,240			—			—		—	153,240
	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
	Balance at December 31, 2013		9,353,240			2,799,258			11,999,258		492,893	24,644,649

	(1) Unit-based compensation awards are presented net of 31,083 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, if any, to priority income allocations in an amount equal to incentive cash distributions allocated 100% to our general partner.
	The calculation of net income allocated to the partners is as follows (in thousands, except per unit amounts):


			Year Ended December 31,
			2013				2012
	Net income attributable to partners		$	47,830			$	8,410
	Net income attributable to partners		$	47,830			$	8,410
	General partner's ownership interest		2		%		2		%
	Less: General partner's allocated interest in net income		957				168
	Less: General partner's allocated interest in net income		957				168
	Limited partners' interest in net income:		46,873				8,242
	Limited partners' interest in net income:		46,873				8,242
	Limited partners' allocated interest in net income - (common)		$	23,490			$	4,121
			$	23,490			$	4,121
	Limited partners' allocated interest in net income - (subordinated)		$	23,383			$	4,121
			$	23,383			$	4,121
	Percentage Allocations of Available Cash from Operating Surplus
	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 the unitholders in any available cash from operating surplus 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 our general partner has contributed any additional capital necessary to maintain its general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.


			Total Quarterly		Marginal Percentage
			Distribution per Unit		Interest in Distributions
			Target Amount		Unitholders			General Partner
	Minimum quarterly distribution		$0.38		98	%		2	%
	First target distribution		above $0.37500 up to $0.43125		98	%		2	%
	Second target distribution		above $0.43125 up to $0.46875		85	%		15	%
	Third target distribution		above $0.46875 up to $0.56250		75	%		25	%
	Thereafter		above $0.56250		50	%		50	%
	Cash distributions
	Our partnership agreement sets forth the calculation to be used to determine the amount and priority of the minimum cash distributions that the common and subordinated unitholders and general partner will receive. Our minimum quarterly distributions are declared subsequent to quarter end. The table below summarizes the minimum quarterly distributions related to our quarterly financial results:


	Quarter Ended		Total Quarterly Distribution Per Unit		Total Quarterly Distribution Per Unit, Annualized		Total Cash Distribution (in thousands)		Date of Distribution	Unitholders Record Date
	31-Dec-13		$0.42		$1.66		$10,228		February 13, 2014	February 4, 2014
	30-Sep-13		$0.41		$1.62		$9,933		November 14, 2013	November 7, 2013
	30-Jun-13		$0.40		$1.58		$9,687		August 13, 2013	August 6, 2013
	31-Mar-13		$0.39		$1.54		$9,428		May 15, 2013	May 7, 2013
	December 31, 2012 (from November 7, 2012) (1)		$0.22		$0.90		$5,486		February 14, 2013	February 6, 2013
	(1) The quarterly cash distribution for the three months ended December 31, 2012 was calculated as the minimum quarterly cash distribution of $0.375 per unit per quarter, or $1.50 per unit on an annualized basis, prorated for the period beginning November 7, 2012, the date the Partnership commenced operations.
	The allocation of total quarterly cash distributions to general and limited partners is as follows for the years ended December 31, 2013 and 2012. Our distributions 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,
		2013				2012
General partner's distributions		$	785			$	110
General partner's distributions		$	785			$	110

Limited partners' distributions:
Common		19,292				2,688
Common		19,292				2,688
Subordinated		19,199				2,688
Subordinated		19,199				2,688
Total cash distributions		$	39,276			$	5,486
Total cash distributions		$	39,276			$	5,486

Cash distributions per unit		$	1.6			$	0.224
Cash distributions per unit		$	1.6			$	0.224

Equity_Based_Compensation_Note

Equity Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2013
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 $0.5 million of unit-based compensation expense related to the Partnership during the year ended December 31, 2013. The fair value of our phantom units 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 during the year ended December 31, 2013 was $4.2 million. No phantom units vested during the years ended December 31, 2012 and 2011. As of December 31, 2013, there was $0.8 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 4.0 years. A summary of our unit award activity for the twelve months ended December 31, 2013 is set forth below:



			Number of Phantom Units	Weighted-Average Grant Price
	Non-vested	1-Jan-13	494,883	$	22.65

	Granted		7,500	$	34.12

	Vested		184,323	$	22.68

	Forfeited		43,108	$	22.65

	Non-vested	December 31, 2013	274,952	$	22.94

	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 years ended December 31, 2012 and 2011. The DKL Predecessor recognized additional compensation expense related to equity-based compensation awards to related party employees of $0.5 million for both the years ended December 31, 2012, and 2011 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 Omnibus Agreement (as defined in Note 18—Related Party Transactions).

Segment_Data_Notes

Segment Data (Notes)	12 Months Ended
	Dec. 31, 2013
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, 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 the segment contribution margin. Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization.
	On July 26, 2013, we acquired the Tyler Terminal and Tank Assets from Delek. Our and our Predecessors' historical financial statements have been retrospectively adjusted to reflect the results of operations attributable to the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented. The results of the Tyler Terminal and the Tyler Tank Assets are included in the wholesale marketing and terminalling segment and the pipelines and transportation segment, respectively.
	The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in thousands):


			As of and For the Year Ended December 31, 2013 (1)
	(In thousands)		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Net sales (excluding intercompany fees and sales)		$	60,237		$	847,191		$	907,428

	Operating costs and expenses:
	Cost of goods sold		764			810,600			811,364

	Operating expenses		22,903			7,399			30,302

	Segment contribution margin		$	36,570		$	29,192		65,762

	General and administrative expenses								6,856

	Depreciation and amortization								12,436

	Loss on disposal of assets								166

	Operating income								$	46,304

	Total assets		$	164,608		$	110,196		$	274,804

	Capital spending (excluding business combinations) (2)		$	6,905		$	2,493		$	9,398

	(1) The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

	(2) Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition


			As of and For the Year Ended December 31, 2012 (1)
			Predecessors
	(In thousands)		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Net sales (excluding intercompany fees and sales)		$	33,539		$	989,047		$	1,022,586

	Operating costs and expenses:
	Cost of goods sold		—			959,434			959,434

	Operating expenses		24,155			6,242			30,397

	Segment contribution margin		$	9,384		$	23,371		32,755

	General and administrative expenses								9,150

	Depreciation and amortization								10,120

	Loss on disposal of assets								9

	Operating income								$	13,476

	Total assets		$	183,204		$	100,112		$	283,316

	Capital spending (excluding business combinations) (2)		$	22,146		$	4,613		$	26,759



(1)	The information presented is adjusted to include the results of operations of the Tyler Predecessor. Prior to the completion of the Offering and the Tyler Acquisition, our Predecessors did not record revenues for intercompany trucking, terminalling, storage and short-haul pipeline transportation services.


(2)	Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition.



		As of and For the Year Ended December 31, 2011 (1)
		Predecessors
(In thousands)		Pipelines and Transportation (2)			Wholesale Marketing and Terminalling			Consolidated
Net sales (excluding intercompany fees and sales)		$	21,878		$	722,201		$	744,079

Operating costs and expenses:
Cost of goods sold		—			700,505			700,505

Operating expenses		15,415			4,052			19,467

Segment contribution margin		$	6,463		$	17,644		24,107

General and administrative expenses								6,483

Depreciation and amortization								6,061

Gain on disposal of assets								(2		)
Operating income								$	11,565

Total assets		$	133,257		$	89,902		$	223,159

Capital spending (excluding business combinations) (3)		$	5,905		$	1,225		$	7,130



-1	The information presented is adjusted to include the results of operations of the Tyler Predecessor. Prior to the completion of the Offering and the Tyler Acquisition, our Predecessors did not record revenues for intercompany trucking, terminalling, storage and short-haul pipeline transportation services.


-2	The operating results presented are for the 247 days and 12 days, respectively, Delek operated the El Dorado Refinery and the Paline Pipeline System in 2011.

(3)	Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition.

Fair_Value_Measurements_Notes

Fair Value Measurements (Notes)

12 Months Ended

Dec. 31, 2013

Fair Value Measurements [Abstract]

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, Fair Value Measurements ("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 sale contracts are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, 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 over the counter commodity swaps are valued using quotations provided by brokers based on exchange pricing and/or price index developers such as Platts or Argus. These are classified as Level 2.

The fair value hierarchy for our financial assets accounted for at fair value on a recurring basis was as follows: (in thousands):

As of December 31, 2013

Level 1

Level 2

Level 3

Total

Assets

Interest rate derivatives

—

116

—

116

As of December 31, 2012, there was a nominal amount of financial liabilities accounted for at fair value on a recurring basis.

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, Derivatives and Hedging - Other Presentation Matters ("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. As of December 31, 2012, a nominal amount of net derivative positions are included in other current assets and other current liabilities, respectively on the accompanying consolidated balance sheets.

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 the cash collateral arising from these derivative positions. As of December 31, 2013, no cash collateral was held by counterparty brokerage firms. As of December 31, 2012, a nominal amount of cash collateral was held by counterparty brokerage firms.

Derivative_Instruments_Notes

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedges, Assets [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.
	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. During the years ended December 31, 2013 and 2012, 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.
	From time to time, we may also enter into interest rate hedging agreements to limit variable interest rate exposure under the Amended and Restated Credit Agreement. The prior 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. 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.
	The table below presents the fair value of our derivative instruments, as of December 31, 2013. As of December 31, 2012, there was a nominal amount of financial liabilities accounted for at fair value on a recurring basis (in thousands).


			December 31, 2013
	Derivative Type	Balance Sheet Location	Assets			Liabilities
	Derivatives not designated as hedging instruments:
	Interest rate derivatives	Other long term assets	$	116		$	—

	Gains (losses) recognized associated with derivatives not designated as hedging instruments for the years ended December 31, 2013 and 2012 were as follows (in thousands):


			Year Ended December 31,
	Derivative Type	Income Statement Location	2013			2012
						Predecessors
	Interest rate derivatives	Interest expense	(106		)	—

	Commodity derivatives	Cost of goods sold	(614		)	85

		Total	$	(720	)	$	85

	There were no unrealized gains related to these forward fuel contracts held on the consolidated balance sheets as of December 31, 2013 and nominal unrealized gains as of December 31, 2012.

Income_Taxes_Notes

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	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 Partnership had a tax benefit of $14.0 million for the year ended December 31, 2012. For the period 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 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.

	Significant components of our deferred tax assets and liabilities, reported separately in the accompanying combined financial statements, as of December 31, 2013 and 2012, are as follows (in thousands):


			December 31,
			2013				2012
	Current Deferred Taxes:
	Accrued reserves		$	6			$	1

	Tank and pipeline inspection liabilities		8				2

	Contingent liabilities		—				11

	Depreciation and amortization		(2		)		—

	Total current deferred tax assets		12				14


	Non-Current Deferred Taxes:
	Depreciation and amortization		(370		)		(36		)
	Asset retirement obligations		4				1

	Tank and pipeline inspection liabilities		30				6

	Contingent liabilities		12				13

	Other		—				(1		)

	Total non-current deferred tax liabilities		(324		)		(17		)
	Total net deferred tax liabilities		$	(312	)		$	(3	)

	The total current deferred tax assets and liabilities, respectively, excluding the valuation allowance, were nominal as of December 31, 2013 and December 31, 2012. The total non-current deferred tax assets and liabilities, respectively, excluding the valuation allowance, were nominal and $0.4 million as of December 31, 2013 and nominal as of December 31, 2012.

	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,
			2013				2012				2011
	Provision for federal income taxes at statutory rate		$	—			$	4,047			$	6,304

	State income taxes, net of federal tax provision		794				(58		)		255

	Valuation allowance		—				193				(1,145		)

	Permanent differences		—				300				15

	Conversion to partnership		—				(18,534		)		—

	Other items		(37		)		28				(66		)

	Income tax (benefit) expense		$	757			$	(14,024	)		$	5,363


	Income tax expense (benefit) is as follows (in thousands):



		Year Ended December 31,
		2013				2012				2011
Current		$	448			$	4,738			$	9,691

Deferred		309				(18,762		)		(4,328		)

		$	757			$	(14,024	)		$	5,363


Deferred income tax expense above is reflective of the changes in deferred tax assets and liabilities during the current period.

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, 2013 and 2012, income taxes payable of $0.4 million and a nominal amount, respectively, were included in accounts receivable/payable from related parties in the accompanying consolidated balance sheets. Taxes that are determined on a combined 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 are no uncertain tax positions recorded as of December 31, 2013, 2012 or 2011 and there were no interest or penalties recognized related to uncertain tax positions for the years ended December 31, 2013, 2012 or 2011. 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
Commitments and Contingencies (Notes)	Dec. 31, 2013
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 FERC. 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 will comply with other 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, beginning on July 1, 2013, by the amount of any change in FERC oil pipeline index or, in the case of the east Texas marketing agreement and the Tyler Throughput and Tankage Agreement, to other inflation based indexes; 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.
	Environmental Health and Safety
	We are subject to various federal, state and local environmental and safety laws enforced by agencies including the U.S. Environmental Protection Agency (the "EPA"), the U.S. Department of Transportation ("DOT") / Pipeline and Hazardous Materials Safety Administration, the U.S. 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 "ADEQ") 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, 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.
	Magnolia Station Crude Oil Release
	On March 9, 2013, a release of crude oil was detected within a pumping facility at our Magnolia Station located west of Delek's El Dorado, Arkansas refinery (the "El Dorado Refinery"). The pumping facility is owned by our subsidiary SALA Gathering Systems, LLC. Since detecting the release we have worked to contain the release, recover the released crude oil and remediate those areas impacted by the release, coordinating our efforts with the EPA and state authorities to restore the impacted area to the satisfaction of the appropriate regulatory authorities. As of the date of this filing, we believe we have substantially completed all necessary remediation, restoration and monitoring of the areas affected by the crude oil release, although there are on-going discussions with ADEQ regarding whether additional monitoring or remediation of soil may be necessary. The release did not impact the delivery of crude oil from the Magnolia Station to the El Dorado Refinery and did not interrupt the operations of the El Dorado Pipeline connected to the Magnolia Station.
	We believe the total costs and liabilities associated with this event are immaterial to our operations and financial results as Delek is required, pursuant to the terms of the Omnibus Agreement (as described in Note 18—Related Party Transactions) to pay to us any costs in excess of $0.25 million with respect to this event that we incurred as a result of the failure at the pumping facility and resulting release.
	Macedonia Crude Oil Release
	On October 7, 2013, a release of crude oil was identified from a gathering line near Macedonia, Arkansas. Approximately 40 barrels of crude oil were recovered from an adjacent small creek. Other than maintaining booms on a portion of the creek, cleanup operations for the creek were essentially concluded in November 2013; however, remediation of impacted soils along the pipeline remains to be completed. Based on current information available to us, we do not believe the total costs associated with this event, 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.
	Contracts and Agreements
	Substantially all of the petroleum products we sell in west Texas are purchased from two suppliers, Noble Petro, Inc. ("Noble Petro") and on Asset Services, L.P. ("Magellan"). Under the terms of a supply contract (the "Abilene Contract") with Noble Petro, we are able 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. There are no options to renew the contract.
	Under the terms of our contract with Magellan (the "East Houston contract"), we had in 2013 the right to purchase up to 7,000 bpd of refined products for resale at third-party terminals located in Aledo, Odessa and Frost, Texas along the Magellan Orion Pipeline. We owned the inventory purchased under the East Houston contract. To hedge our exposure to fluctuations in commodity prices for the period between our purchase of products from Magellan and subsequent sales to our customers, from time to time we entered into Gulf Coast product swap arrangements with respect to the products we purchased. The East Houston contract was terminated in January 2014. We are currently discussing the possibility of a new contract with Magellan and are purchasing spot barrels on similar terms from third parties for sale to wholesale customers.
	Letters of Credit
	As of December 31, 2013, we had in place letters of credit totaling $12.0 million under the Amended and Restated Credit Agreement primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn by beneficiaries of these letters of credit at December 31, 2013.
	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, 2013, 2012 and 2011 totaled $0.5 million, $0.5 million, and $0.3 million, respectively.
	We have a five-year ground lease agreement with Lion Oil effective November 7, 2012 for the land on which an above ground storage tank and related facilities are located. The land measures approximately seven acres of Lion Oil's refinery site. The tank and related facilities are used for the storage and throughput of such crude oil or other hydrocarbon substances or any resulting refined products. The fees paid to Lion Oil were insignificant for 2013.
	In connection with the Tyler Acquisition, we and Delek entered into a lease and access agreement with respect to the real property at the Tyler Terminal and Tank Assets. Under this agreement, we will lease from Delek the real property on which the Tyler Terminal and Tank Assets are located for $100 annually, paid in advance, with an initial term of 50 years with automatic renewal for a maximum of four successive 10-year periods thereafter.

Related_Party_Transactions_Not

Related Party Transactions (Notes)

12 Months Ended

Dec. 31, 2013

Related Party Transactions [Abstract]

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; 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 .89 (3)

Refined Products Pipelines

Nov-12

40,000

0.105

SALA Gathering System

Nov-12

Crude oil gathering

14,000

$ 2.35 (3)

East Texas Crude Logistics System:

Crude Oil Pipelines

Nov-12

15-May

Crude oil transportation and storage

35,000

$ 0.42 (4)

Storage

Nov-12

N/A

$261,480/month

East Texas Marketing

Nov-12

10 (5)

Marketing products for Tyler Refinery

50,000

$ .6065/bbl(5)

Memphis Terminal

Nov-12

15-May

Dedicated terminalling services

10,000

0.52

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

0.52

Terminalling

Nov-12

5,000

0.52

Storage

Nov-12

N/A

$52,250/month

Tyler Throughput and Tankage:

Refined Products Throughput

Jul-13

16-Aug

Dedicated Terminalling and storage

50,000

0.35

Storage

Jul-13

N/A

$841,667/month

Tyler Lease and Access

Jul-13

Real property lease

N/A

$100 annually

Tyler Site Services

Jul-13

16-Aug

Shared services

N/A

$200,000 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

$63,000/month (7)

-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 $0.638/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. Even though the Big Sandy Terminal was not operational for a majority of the year ended December 31, 2013, as the pipeline required maintenance in order to return it to service, Delek paid to us the minimum terminal and storage fees for the Big Sandy Terminal pursuant to the agreement above. The terminal was available for use by Delek, beginning in the fourth quarter 2013.

-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.

El Dorado Refinery Crude Oil and Refined Products Supply and Offtake Arrangement

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 and North Little Rock terminals. 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 throughout 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 the commercial agreements described above, the Partnership has entered into the following agreements with Delek:

Omnibus Agreement

The Partnership entered into an omnibus agreement with Delek, our general partner, our subsidiary, Delek Logistics Operating, LLC ("OpCo"), Delek, Lion Oil, and certain of the Partnership’s and Delek’s other subsidiaries upon the completion of the Offering on November 7, 2012. We refer to this omnibus agreement, as subsequently amended, as the “Omnibus Agreement.”

On July 26, 2013, in connection with the acquisition from Delek of the refined products terminal and 96 storage tanks and ancillary assets adjacent to the Tyler Refinery from Delek, the Partnership entered into an amendment and restatement of the Omnibus Agreement (the “First Omnibus Amendment”). The First Omnibus Amendment, included the following, among other things: (i) certain 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) certain modifications of the indemnification provisions under the Omnibus Agreement in favor of the Partnership with respect to certain environmental matters, and (iii) the increase of the annual administrative fee payable by us to Delek under the Omnibus Agreement for corporate general and administrative services.

The annual administrative fee payable by the Partnership to Delek for corporate general and administrative services that Delek and its affiliates provide under the First Omnibus Amendment, increased from $2.7 million to $3.0 million, which is prorated and payable monthly. We paid Delek approximately $3.7 million pursuant to the Omnibus Agreement, which includes $2.8 million related to general and administrative services and $0.9 million related to insurance coverage during the year ended December 31, 2013. Delek paid us approximately $0.9 million pursuant to the Omnibus Agreement during the year ended December 31, 2013 as indemnification relative to the Paline Pipeline System.

Under the Omnibus Agreement, Delek has agreed to reimburse us for certain expenses that we incur for inspections, maintenance and repairs to any storage tanks we acquired in the Tyler Acquisition to cause such storage tanks to comply with applicable regulatory and/or industry standards. Delek is also required to reimburse us for certain expenses that we incur for inspections, maintenance and repairs to any 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. Furthermore, under the Omnibus Agreement, Delek was required to reimburse us for all non-discretionary maintenance capital expenditures with respect to the Tyler Terminal and Tank Assets in excess of $0.4 million for the period from July 26, 2013 through September 30, 2013. Delek was also required to reimburse us for non-discretionary maintenance capital expenditures with respect to all assets transferred from Delek to the Partnership in excess of $1.4 million for the period from September 30, 2013 through December 31, 2013.

For additional information regarding the Omnibus Agreement, see “Note 20—Subsequent Events—El Dorado Terminal and Tankage Acquisition”

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. 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, including operating and maintaining flow and pressure control, maintaining and repairing our pipelines, storage and terminalling facilities and related assets, conducting routine operational activities, and managing transportation and logistics, contract administration, crude oil and refined product measurement, database mapping, rights-of-way, materials, engineering support and such other services as our general partner and Delek may mutually agree upon from time to time. We and/or our general partner reimbursed Delek for such services under the operation and management services agreement. We and our subsidiaries paid Delek approximately $5.9 million pursuant to this agreement during the year ended December 31, 2013.

On July 26, 2013, in connection with the Tyler Acquisition, the Partnership, our general partner and Delek Logistics Services Company terminated the operation and management services agreement. We continued to reimburse our general partner for the services it provides to us under our partnership agreement. We reimbursed our general partner $6.5 million pursuant to the partnership agreement during the year ended December 31, 2013.

Other Agreements

Paline Pipeline System Capacity Reservation. In 2011, prior to our purchase of the Paline Pipeline, a major integrated oil company contracted with the prior owner of the Paline Pipeline System to reverse the pipeline to primarily run southbound. In exchange, the oil company agreed to pay for use of 100% of such southbound capacity for a fee of $450,000 and $529,250 per month in 2012 and 2013, respectively. The agreement will thereafter be subject to annual escalation based on the change in the producer price index for finished goods during any renewal periods. The monthly fees payable to us under our agreement with this customer will increase proportionately to the extent throughput volumes are above 30,000 bpd. To the extent we are unable to provide our customer with 30,000 barrels of throughput capacity during a given month, the monthly fee may be reduced accordingly. The agreement extends through December 31, 2014 and will renew automatically each year unless terminated by either party at least six months prior to the year end.

Pursuant to the terms of the usage contract, this customer was required to make only payments of $229,000 per month for this capacity until the final segment of the reversal of the Paline Pipeline System was completed, and we entered into a connection agreement with an affiliate of the customer to connect our system with such affiliate's tanks. We completed our work on the fourth segment of the reversal in October 2012. However, a connection agreement was not fully executed until April 2013. Even though our customer had not yet completed the work on its tanks, because we completed our necessary work, we believe we were owed the full payment under the contract beginning in November 2012. Our customer paid only $229,000 per month in 2012 and during the first quarter 2013. Pursuant to the Omnibus Agreement, Delek is required to indemnify us during the period from November 1, 2012 through December 31, 2013 for any lost service fees attributable to the failure of our customer to pay 100% of the full monthly fee. Therefore, Delek indemnified us for lost service fees related to the Paline Pipeline System in 2012 and during the first quarter 2013. Beginning in the second quarter of 2013 and for the rest of 2013, each month we received the entire monthly amount payable to us of $529,250.

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 Offering and the Tyler Acquisition, we were not allocated certain corporate costs. These costs were primarily allocated based on a percentage of salaries expense and property, plant and equipment costs. In the opinion of management, the methods for allocating these costs are reasonable. It is not practicable to estimate the costs that would have been incurred by us if we had been operated on a stand-alone basis.

Summary of Transactions

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,

2013

2012

2011

Predecessors

Revenues

77,272

43,216

34,266

Operating and maintenance expenses (1)

14,718

3,394

3,291

General and administrative expenses (2)

3,341

4,944

3,125

(1)

Operating and maintenance expenses include costs allocated to the Tyler Predecessor for operating support provided to the Tyler Predecessor by Delek Refining, including certain labor related costs, property and liability insurance costs and certain other operating expenses. The costs that were allocated to us were $1.4 million for the year ended December 31, 2013, and $2.7 million, for each of the years ended December 31, 2012 and 2011.

(2)

General and administrative expenses include costs allocated to the Tyler Predecessor for general and administrative support provided to the Tyler Predecessor by Delek Refining, including services such as corporate management, risk management, accounting and human resources. The costs that were allocated to us were $0.5 million, $0.8 million and $0.7 million for the years ended December 31, 2013, 2012 and 2011, 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. On January 23, 2014, we declared a quarterly cash distribution of $0.415 per unit based on the results of the fourth quarter of 2013, which was paid on February 13, 2014.

Selected_Quarterly_Financial_D

Selected Quarterly Financial Data (Notes)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information [Text Block]	'
	Selected Quarterly Financial Data (Unaudited)

	Quarterly financial information for the years ended December 31, 2013 and 2012 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On July 26, 2013, we acquired the Tyler Terminal and Tank Assets from Delek. Our and our Predecessors' historical data has been retrospectively adjusted to reflect the results of operations attributable to the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.



			For the Three Month Periods Ended
			31-Mar-13		30-Jun-13		30-Sep-13			31-Dec-13
	Net sales		$	210,894	$	230,141	$	243,295		$	223,097

	Operating income		$	10,309	$	9,766	$	12,887		$	13,342

	Net income		$	9,370	$	8,896	$	11,386		$	11,325

	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





			For the Three Month Periods Ended
			March 31, 2012 (1)		June 30, 2012 (1)		September 30, 2012 (1)			December 31, 2012 (1)
	Net sales		$	239,084	$	262,480	$	271,806		$	249,216

	Operating income		$	3,730	$	2,031	$	2,560		$	5,155

	Net income (loss) (3)		$	1,322	$	584	$	(544	)	$	23,456

	Limited partners' interest in net income									$	8,242

	Net income per limited partner unit: (2)
	Common (basic)									$	0.34

	Common (diluted)									$	0.34

	Subordinated - Delek (basic and diluted)									$	0.34




	(1)	The information presented includes the results of operations of the DKL Predecessor for periods presented through November 6, 2012 and of the Tyler Predecessor for all periods presented, and of the Partnership for the period beginning November 7, 2012, the date the Partnership commenced operations.

	(2)	Net income per unit is only calculated for the Partnership after the Offering as no units were outstanding prior to November 7, 2012.

	(3)	Net income for the year ended December 31, 2012 includes a one-time tax benefit of $18.5 million. The majority of the Partnership's deferred tax assets and liabilities relates to the Predecessor's conversion from a corporation to a partnership and as a result of such conversion we are not subject to federal income taxes. The conversion from a taxable corporation to a passthrough resulted in this one-time tax benefit.

Subsequent_Events_Notes

Subsequent Events (Notes)	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	Subsequent Events
	Distribution Declaration
	On January 23, 2014, our general partner's board of directors declared a quarterly cash distribution of $0.415 per share, paid on February 13, 2014, to unitholders of record on February 4, 2014.
	El Dorado Terminal and Tankage Acquisition
	On February 10, 2014, the Partnership, through OpCo, completed a transaction with Lion Oil, pursuant to which OpCo acquired a refined products terminal, storage tanks and ancillary assets adjacent to the El Dorado Refinery from Lion Oil (the "El Dorado Transaction"). We acquired the El Dorado assets, defined below, to complement our existing assets and provide attractive returns for our unitholders. 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. As the initial accounting for the El Dorado Transaction was incomplete at the time the financial statements were available to be issued, there are no pro forma disclosures available for the year ended December 31, 2013.
	The assets acquired in the El Dorado Transaction consist of:


	•	The refined products terminal located at the El Dorado Refinery (the "El Dorado Terminal"), 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 bpd. For the year ended December 31, 2012, approximately 12,649 bpd of refined products were throughput at the El Dorado Terminal.


	•	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 (such storage tanks and certain ancillary assets, the "El Dorado Storage Tanks"). The El Dorado Storage Tanks, together with the El Dorado Terminal, are sometimes hereinafter referred to as the "El Dorado Assets."
	In connection with the El Dorado Transaction, the Partnership entered into and amended, as applicable, the following definitive agreements:
	El Dorado Throughput and Tankage Agreement. On February 10, 2014, in connection with the El Dorado Transaction, Lion Oil and OpCo, and, for limited purposes, J. Aron, entered into the El Dorado Throughput and Tankage Agreement. Under the El Dorado Throughput and Tankage Agreement, OpCo will provide Lion Oil with throughput and storage services in return for throughput and storage fees. The initial term of the El Dorado Throughput and Tankage Agreement is eight years and Lion Oil, at its sole option, may extend the term for two renewal terms of four years each.
	Second Omnibus Amendment. On February 10, 2014, in connection with the El Dorado Transaction, the Partnership entered into a second amendment and restatement of Omnibus Agreement with our general partner, OpCo, certain of the Partnership's other subsidiaries, Delek, Lion Oil and Delek Refining (the "Second Omnibus Amendment"). The Second Omnibus Amendment included, among other things: (i) certain modifications in the reimbursement by Delek US and certain of its subsidiaries under the Omnibus Agreement for certain operating expenses and capital expenditures incurred by the Partnership or its subsidiaries; (ii) certain modifications of the indemnification provisions under the Omnibus Agreement in favor of the Partnership with respect to certain environmental matters; and (iii) the increase of the annual administrative fee payable by us to Delek under the Omnibus Agreement for corporate general and administrative services from $3.0 million to $3.3 million, which is prorated and payable monthly.
	El Dorado Lease and Access Agreement. On February 10, 2014, in connection with the El Dorado Transaction, Lion Oil and OpCo entered into the El Dorado Lease and Access Agreement (the "El Dorado Lease"). Under the El Dorado Lease, OpCo will lease from Lion Oil the real property on which the El Dorado Assets are located. The El Dorado Lease has an initial term of 50 years with automatic renewal for a maximum of four successive 10-year periods thereafter.

	El Dorado Site Services Agreement. On February 10, 2014, in connection with the El Dorado Transaction, Lion Oil and OpCo entered into the El Dorado Site Services Agreement. Under the El Dorado Site Services Agreement, Lion Oil will provide OpCo with shared use of certain services, materials and facilities that are necessary to operate and maintain the El Dorado Assets as currently operated and maintained. The term of the El Dorado Site Services Agreement is co-terminous with the El Dorado Lease discussed above.

Accounting_Policies_Policies

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
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.
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. As of December 31, 2013 and 2012, any cash equivalents consisted primarily of overnight investments in U.S. Government obligations, bank repurchase obligations collateralized by U.S. Government obligations and bank money market accounts.
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, 2013 and 2012.
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 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, 2013, 2012, or 2011.
	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 2013, 2012 and 2011. 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.
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 hedging 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 monthly basis, utilizing valuations from third party financial and brokerage institutions. During the years ended December 31, 2013, 2012, and 2011, we did not elect to apply hedging treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of operations.
	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 the cash collateral arising from 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 statement of position 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, 2013 or 2012, 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.
	The reconciliation of the beginning and ending carrying amounts of asset retirement obligations as of December 31, 2013 and 2012 is as follows (in thousands):


			December 31,
			2013			2012
	Beginning balance		$	3,177		$	2,990

	Liabilities settled		(400		)	—

	Accretion expense		216			187

	Ending balance		$	2,993		$	3,177


	In order to determine fair value, management must make certain estimates and assumptions including, among other things, projected cash flows, a credit-adjusted risk-free rate and an assessment of market conditions that could significantly impact the estimated fair value of the asset retirement obligation.
Sales Use and Excise Taxes, Policy [Policy Text Block]	'
	Revenue Recognition
	Revenues for products sold are recorded at the point of sale upon delivery of product, which is the point at which title to the product is transferred, and when payment has either been received or collection is reasonably assured. Service revenues are recognized as crude oil and refined products are shipped through, delivered by or stored in our pipelines, 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, 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 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 financial statements.
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.
	Lease expense for all operating leases, including the Tyler Predecessor, totaled $0.5 million, $0.5 million, and $0.3 million for the years ended December 31, 2013, 2012, and 2011, respectively.
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 his, her or its share of items of income, gain, loss and deduction in computing his, her or 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 the 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.
Comprehensive Income, Policy [Policy Text Block]	'
	Comprehensive Income
	Comprehensive income for the years ended December 31, 2013, 2012, and 2011 was equivalent to net income.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	New Accounting Pronouncements
	In July 2012, the FASB issued guidance regarding testing indefinite-lived intangible assets for impairment that gives companies the option to perform a qualitative assessment before calculating the fair value of the indefinite-lived intangible asset. Under the guidance, if this option is selected, a company is not required to calculate the fair value of the indefinite-lived intangible unless the entity determines it is more likely than not that its fair value is less than its carrying amount. In October 2012, the FASB issued guidance regarding the application of the qualitative assessment permitted under the Accounting Standards Update 2012-02, issued in July. The guidance requires companies to focus on the significant inputs used to determine the fair value of indefinite-lived intangible assets when companies opt to perform the qualitative assessment. Companies must then evaluate the impact of certain events and circumstances that could have affected those inputs and weigh the identified factors prior to concluding whether the asset is impaired. As significant judgment is applied to conclude that an indefinite-lived intangible asset is not impaired based on a qualitative assessment, the analyses performed by the Company should be supported by clear documentation of the factors considered, including any necessary quantitative calculations. The guidance is effective for interim and annual reporting periods beginning January 1, 2013, but early adoption is permitted. The adoption of this guidance did not affect our business, financial position or results of operations.
	In December 2011, the FASB issued guidance requiring the disclosure of information about offsetting and related arrangements to enable users of financial statements to understand the effect of these arrangements on financial position. The guidance requires the disclosure of both gross information and net information about both instruments and transactions eligible for offset in the balance sheet and instruments and transactions subject to an agreement similar to a master netting arrangement. In January 2013, the FASB issued an update limiting the scope of the offsetting disclosure requirements established by the original guidance, to certain derivatives (including bifurcated embedded derivatives), repurchase agreements and reverse repurchase agreements, and securities lending and securities borrowing transactions that are eligible for offset on the balance sheet or are subject to an agreement similar to a master netting arrangement, irrespective of whether they are offset on the balance sheet. This update amends the guidance that required companies to apply the requirements to all recognized financial instruments. The original and updated guidance is effective for interim and annual reporting periods beginning January 1, 2013 and retrospectively for all periods presented on the balance sheet. The adoption of this guidance did not affect our business, financial position or results of operations, but resulted in additional disclosures (see Note 14).

Net_Income_Per_Unit_Net_Income

Net Income Per Unit Net Income Per Unit (Policies)	12 Months Ended
Net Income Per Unit Net Income Per Unit (Policies)	Dec. 31, 2013
Net Income Per Unit [Abstract]	'
Net income per unit, Policy [Policy Text Block]	'
Net income per unit, Policy [Policy Text Block]	We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating security. 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 the general partner’s 2% interest and incentive distributions, if any, 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 distributions, if any, 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.

Goodwill_Goodwill_Policies

Goodwill Goodwill (Policies)	12 Months Ended
Goodwill Goodwill (Policies)	Dec. 31, 2013
Goodwill [Abstract]	'
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, 2013, 2012, or 2011.
	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 2013, 2012 and 2011. 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.

Fair_Value_Measurements_Fair_V

Fair Value Measurements Fair Value Measurements (Policies)	12 Months Ended
Fair Value Measurements Fair Value Measurements (Policies)	Dec. 31, 2013
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 sale contracts are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, 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 over the counter commodity swaps are valued using quotations provided by brokers based on exchange pricing and/or price index developers such as Platts or Argus. These are classified as Level 2.

Accounting_Policies_Tables

Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
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,
			2013			2012

	Land and land improvements		$	1,931		$	1,084

	Building and building improvements		944			923

	Pipelines and terminals		205,866			175,456

	Asset retirement obligations		1,999			1,998

	Other equipment		2,219			1,557

	Construction in process		22,629			35,030

			235,588			216,048

	Less: accumulated depreciation		(36,306		)	(24,991		)
			$	199,282		$	191,057


	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2013 and 2012 are as follows (in thousands):


			As of and For the Year Ended December 31, 2013
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	174,823		$	60,765		$	235,588

	Less: Accumulated depreciation		(22,032		)	(14,274		)	(36,306		)
	Property, plant and equipment, net		$	152,791		$	46,491		$	199,282

	Depreciation expense		$	8,756		$	2,617		$	11,373





			As of and For the Year Ended December 31, 2012
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	168,196		$	47,852		$	216,048

	Less: Accumulated depreciation		(13,642		)	(11,349		)	(24,991		)
	Property, plant and equipment, net		$	154,554		$	36,503		$	191,057

	Depreciation expense		$	6,771		$	2,285		$	9,056

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, 2013 and 2012 is as follows (in thousands):


			December 31,
			2013			2012
	Beginning balance		$	3,177		$	2,990

	Liabilities settled		(400		)	—

	Accretion expense		216			187

	Ending balance		$	2,993		$	3,177

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
North Little Rock Terminal [Member]	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The preliminary allocation of the aggregate purchase price of the North Little Rock Terminal as of December 31, 2013 is summarized as follows (in thousands):


	Property, plant and equipment	$	4,987

	Intangible assets	13

	Total	$	5,000

Business Acquisition, Pro Forma Information [Table Text Block]	'
	Below are the unaudited pro forma consolidated results of operations for the years ended December 31, 2013 and 2012, as if these acquisitions had occurred on January 1, 2012 (in thousands):


			Year Ended December 31,
			2013				2012
	Net sales		$	908,867			$	1,024,025

	Net income		$	42,268			$	26,109

Tyler Terminal and Tanks [Member]	'
Business Acquisition [Line Items]	'
Business Combination, Financial Information [Table Text Block]	'
	Combined Consolidated Balance Sheet as of December 31, 2012


			Delek Logistics				Tyler Terminal and Tank Assets				Delek Logistics Partners, LP
			Partners, LP				(Tyler Predecessor)				31-Dec-12
							(In thousands)
	ASSETS
	Current Assets:
	Cash and cash equivalents		$	23,452			$	—			$	23,452

	Accounts receivable		27,725				—				27,725

	Inventory		14,351				—				14,351

	Deferred tax assets		14				—				14

	Other current assets		169				—				169

	Total current assets		65,711				—				65,711

	Property, plant and equipment:
	Property, plant and equipment		172,300				43,748				216,048

	Less: accumulated depreciation		(18,790		)		(6,201		)		(24,991		)
	Property, plant and equipment, net		153,510				37,547				191,057

	Goodwill		10,454				—				10,454

	Intangible assets, net		12,430				—				12,430

	Other non-current assets		3,664				—				3,664

	Total assets		$	245,769			$	37,547			$	283,316

	LIABILITIES AND EQUITY
	Current liabilities:
	Accounts payable		$	21,849			$	—			$	21,849

	Accounts payable to related parties		10,148				—				10,148

	Fuel and other taxes payable		4,650				—				4,650

	Accrued expenses and other current liabilities		3,615				35				3,650

	Total current liabilities		40,262				35				40,297

	Non-current liabilities:
	Revolving credit facility		90,000				—				90,000

	Asset retirement obligations		1,440				1,737				3,177

	Deferred tax liability		17				—				17

	Other non-current liabilities		9,625				185				9,810

	Total non-current liabilities		101,082				1,922				103,004

	Equity:
	Predecessors division equity		—				35,590				35,590

	Common unitholders - public (9,200,000 units issued and outstanding)		178,728				—				178,728

	Common unitholders - Delek (2,799,258 units issued and outstanding)		(127,129		)		—				(127,129		)

Subordinated unitholders - Delek (11,999,258 units issued and outstanding)		52,875				—				52,875

General Partner unitholders - Delek (489,766 units issued and outstanding)		(49		)		—				(49		)

Total equity		104,425				35,590				140,015

Total liabilities and equity		$	245,769			$	37,547			$	283,316


Combined Consolidated Statements of Income


		Delek Logistics				Tyler Terminal and Tank Assets				Year Ended
		Partners, LP				(Tyler Predecessor)				December 31, 2013
						(In thousands)
Net Sales		$	907,428			$	—			$	907,428

Operating costs and expenses:
Cost of goods sold		811,364				—				811,364

Operating expenses		25,801				4,501				30,302

General and administrative expenses		6,254				602				6,856

Depreciation and amortization		10,686				1,750				12,436

Loss on asset disposals		166				—				166

Total operating costs and expenses		854,271				6,853				861,124

Operating income (loss)		53,157				(6,853		)		46,304

Interest expense, net		4,570				—				4,570

Net income (loss) before income tax expense		48,587				(6,853		)		41,734

Income tax expense		757				—				757

Net income (loss)		47,830				(6,853		)		40,977

Less: (Loss) attributable to Predecessors		—				(6,853		)		(6,853		)

Net income attributable to partners		$	47,830			$	—			$	47,830




						Tyler Terminal and				Year Ended
		Delek Logistics				Tank Assets				December 31, 2012
		Partners, LP				(Tyler Predecessor)				(Predecessors)
						(In thousands)
Net Sales		$	1,022,586			$	—			$	1,022,586

Operating costs and expenses:
Cost of goods sold		959,434				—				959,434

Operating expenses		23,362				7,035				30,397

General and administrative expenses		8,389				761				9,150

Depreciation and amortization		8,675				1,445				10,120

Loss on asset disposals		9				—				9

Total operating costs and expenses		999,869				9,241				1,009,110

Operating income (loss)		22,717				(9,241		)		13,476

Interest expense, net		2,682				—				2,682

Net income (loss) before income tax expense		20,035				(9,241		)		10,794

Income tax benefit		(14,024		)		—				(14,024		)

Net income (loss)		34,059				(9,241		)		24,818

Less: Income (loss) attributable to Predecessors		25,649				(9,241		)		16,408

Net income attributable to partners		$	8,410			$	—			$	8,410



		Delek Logistics				Tyler Terminal and				Year Ended
		Partners, LP				Tank Assets				December 31, 2011
		(DKL Predecessor)				(Tyler Predecessor)				(Predecessors)
						(In thousands)
Net Sales		$	744,079			$	—			$	744,079

Operating costs and expenses:
Cost of goods sold		700,505				—				700,505

Operating expenses		12,940				6,527				19,467

General and administrative expenses		5,795				688				6,483

Depreciation and amortization		4,820				1,241				6,061

Gain on disposal of assets		(2		)		—				(2		)

Total operating costs and expenses		724,058				8,456				732,514

Operating income (loss)		20,021				(8,456		)		11,565

Interest expense, net		2,011				—				2,011

Income (loss) before income tax expense		18,010				(8,456		)		9,554

Income tax expense		5,363				—				5,363

Net income (loss)		12,647				(8,456		)		4,191

Less: (Loss) income attributable to Predecessors		12,647				(8,456		)		4,191

Net income attributable to partners		$	—			$	—			$	—

Hopewell [Member]	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The preliminary allocation of the aggregate purchase price of the Hopewell Pipeline as of December 31, 2013 is summarized as follows (in thousands):


	Property, plant and equipment	$	4,836

	Intangible assets	864

	Total	$	5,700

Business Acquisition, Pro Forma Information [Table Text Block]	'
	Below are the unaudited pro forma consolidated results of operations for the years ended December 31, 2013 and 2012, as if these acquisitions had occurred on January 1, 2012 (in thousands):


			Year Ended December 31,
			2013				2012
	Net sales		$	908,382			$	1,023,540

	Net income		$	41,291			$	25,132

Big Sandy Terminal [Member]	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The allocation of the aggregate purchase price of Big Sandy as of December 31, 2013 is summarized as follows (in thousands):


	Property, plant and equipment	$	8,258

	Intangible assets	1,229

	Goodwill (all expected to be deductible for tax purposes)	1,540

	Total	$	11,027

Nettleton Pipeline [Member]	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The allocation of the aggregate purchase price of the Nettleton Pipeline as of December 31, 2013 is summarized as follows (in thousands):


	Property, plant and equipment	$	8,590

	Intangible assets	2,240

	Goodwill (all expected to be deductible for tax purposes)	1,415

	Total	$	12,245

Nettleton and Big Sandy [Member]	'
Business Acquisition [Line Items]	'
Business Acquisition, Pro Forma Information [Table Text Block]	'
	Below are the pro forma consolidated results of operations of the Predecessor for the year ended December 31, 2012, as if these acquisitions had occurred on January 1, 2012 (amounts in thousands):


			Year Ended December 31,
			2012
	Net sales		$	1,022,715

	Net income		$	24,941

Net_Income_Per_Unit_Tables

Net Income Per Unit (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012
	Net income attributable to partners	$	47,830	$	8,410

	Less: General partner's distribution	785		110

	Less: Limited partners' distribution	19,292		2,688

	Less: Subordinated partner's distribution	19,199		2,688

	Earnings in excess of distributions	$	8,554	$	2,924


	General partner's earnings:
	Distributions	$	785	$	110

	Allocation of earnings in excess of distributions	172		58

	Total general partner's earnings	$	957	$	168


	Limited partners' earnings on common units:
	Distributions	$	19,292	$	2,688

	Allocation of earnings in excess of distributions	4,198		1,433

	Total limited partners' earnings on common units	$	23,490	$	4,121


	Limited partners' earnings on subordinated units:
	Distributions	$	19,199	$	2,688

	Allocation of earnings in excess of distributions	4,184		1,433

	Total limited partner's earnings on subordinated units	$	23,383	$	4,121


	Weighted average limited partner units outstanding:
	Common units - (basic)	12,025,249		11,999,258

	Common units - (diluted)	12,148,774		11,999,258

	Subordinated units - Delek (basic and diluted)	11,999,258		11,999,258


	Net income per limited partner unit:
	Common - (basic)	$	1.95	$	0.34

	Common - (diluted)	$	1.93	$	0.34

	Subordinated - (basic and diluted)	$	1.95	$	0.34

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
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,
			2013			2012

	Land and land improvements		$	1,931		$	1,084

	Building and building improvements		944			923

	Pipelines and terminals		205,866			175,456

	Asset retirement obligations		1,999			1,998

	Other equipment		2,219			1,557

	Construction in process		22,629			35,030

			235,588			216,048

	Less: accumulated depreciation		(36,306		)	(24,991		)
			$	199,282		$	191,057


	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2013 and 2012 are as follows (in thousands):


			As of and For the Year Ended December 31, 2013
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	174,823		$	60,765		$	235,588

	Less: Accumulated depreciation		(22,032		)	(14,274		)	(36,306		)
	Property, plant and equipment, net		$	152,791		$	46,491		$	199,282

	Depreciation expense		$	8,756		$	2,617		$	11,373





			As of and For the Year Ended December 31, 2012
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	168,196		$	47,852		$	216,048

	Less: Accumulated depreciation		(13,642		)	(11,349		)	(24,991		)
	Property, plant and equipment, net		$	154,554		$	36,503		$	191,057

	Depreciation expense		$	6,771		$	2,285		$	9,056

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill [Abstract]	'
Schedule of Goodwill [Table Text Block]	'
	A summary of our goodwill accounts is as follows (in thousands):



	Balance,	December 31, 2010	$	7,499

	Goodwill impairment		—

	Balance,	December 31, 2011	7,499

	Goodwill impairment		—

	Goodwill acquired through the business combinations of Nettleton and Big Sandy		2,955

	Balance,	December 31, 2012	10,454

	Goodwill impairment		—

	Balance,	December 31, 2013	$	10,454

Other_Intangibles_Tables

Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2013
Other Intangible Assets Disclosure [Abstract]	'
Schedule of Intangible Assets [Table Text Block]	'


		Useful			Accumulated
	As of December 31, 2013	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts	11.5	$	12,227	$	(7,885	)	$	4,342

	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	7,916		—			7,916

	Total		$	20,143	$	(7,885	)	$	12,258




		Useful			Accumulated
	As of December 31, 2012	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts	11.5	$	12,227	$	(6,822	)	$	5,405

	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	7,025		—			7,025

	Total		$	19,252	$	(6,822	)	$	12,430

LongTerm_Obligations_and_Short1

Long-Term Obligations and Short-Term Note Payable (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013 (in thousands):


		2014	2015	2016	2017		2018	Thereafter	Total
	Amended and Restated Credit Agreement	—	—	—	$	164,800	—	—	$	164,800

Equity_Tables

Equity (Tables)	12 Months Ended
Equity (Tables)	Dec. 31, 2013
Equity [Abstract]	'
Schedule of Capital Units [Table Text Block]	'
	The table below summarizes the changes in the number of units outstanding through December 31, 2013 (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
	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
	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
	GP units issued to maintain 2% interest	—			—			—		3,127	3,127
	Unit-based compensation awards (1)	153,240			—			—		—	153,240
	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
	Balance at December 31, 2013	9,353,240			2,799,258			11,999,258		492,893	24,644,649
Schedule Of Calculation Of Net Income Applicable To Partners [Table Text Block]	'
	The calculation of net income allocated to the partners is as follows (in thousands, except per unit amounts):


		Year Ended December 31,
		2013				2012
	Net income attributable to partners	$	47,830			$	8,410
	Net income attributable to partners	$	47,830			$	8,410
	General partner's ownership interest	2		%		2		%
	Less: General partner's allocated interest in net income	957				168
	Less: General partner's allocated interest in net income	957				168
	Limited partners' interest in net income:	46,873				8,242
	Limited partners' interest in net income:	46,873				8,242
	Limited partners' allocated interest in net income - (common)	$	23,490			$	4,121
		$	23,490			$	4,121
	Limited partners' allocated interest in net income - (subordinated)	$	23,383			$	4,121
		$	23,383			$	4,121
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 the unitholders in any available cash from operating surplus 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 our general partner has contributed any additional capital necessary to maintain its general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.


		Total Quarterly		Marginal Percentage
		Distribution per Unit		Interest in Distributions
		Target Amount		Unitholders			General Partner
	Minimum quarterly distribution	$0.38		98	%		2	%
	First target distribution	above $0.37500 up to $0.43125		98	%		2	%
	Second target distribution	above $0.43125 up to $0.46875		85	%		15	%
	Third target distribution	above $0.46875 up to $0.56250		75	%		25	%
	Thereafter	above $0.56250		50	%		50	%
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	'
	The table below summarizes the minimum quarterly distributions related to our quarterly financial results:


	Quarter Ended	Total Quarterly Distribution Per Unit		Total Quarterly Distribution Per Unit, Annualized		Total Cash Distribution (in thousands)		Date of Distribution	Unitholders Record Date
	31-Dec-13	$0.42		$1.66		$10,228		February 13, 2014	February 4, 2014
	30-Sep-13	$0.41		$1.62		$9,933		November 14, 2013	November 7, 2013
	30-Jun-13	$0.40		$1.58		$9,687		August 13, 2013	August 6, 2013
	31-Mar-13	$0.39		$1.54		$9,428		May 15, 2013	May 7, 2013
	December 31, 2012 (from November 7, 2012) (1)	$0.22		$0.90		$5,486		February 14, 2013	February 6, 2013
	The calculation of net income allocated to the partners is as follows (in thousands, except per unit amounts):


		Year Ended December 31,
		2013				2012
	Net income attributable to partners	$	47,830			$	8,410
	Net income attributable to partners	$	47,830			$	8,410
	General partner's ownership interest	2		%		2		%
	Less: General partner's allocated interest in net income	957				168
	Less: General partner's allocated interest in net income	957				168
	Limited partners' interest in net income:	46,873				8,242
	Limited partners' interest in net income:	46,873				8,242
	Limited partners' allocated interest in net income - (common)	$	23,490			$	4,121
		$	23,490			$	4,121
	Limited partners' allocated interest in net income - (subordinated)	$	23,383			$	4,121
		$	23,383			$	4,121
	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,
		2013				2012
	General partner's distributions	$	785			$	110
	General partner's distributions	$	785			$	110

	Limited partners' distributions:
	Common	19,292				2,688
	Common	19,292				2,688
	Subordinated	19,199				2,688
	Subordinated	19,199				2,688
	Total cash distributions	$	39,276			$	5,486
	Total cash distributions	$	39,276			$	5,486

	Cash distributions per unit	$	1.6			$	0.224
	Cash distributions per unit	$	1.6			$	0.224

Equity_Based_Compensation_Tabl

Equity Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013 is set forth below:



			Number of Phantom Units	Weighted-Average Grant Price
	Non-vested	1-Jan-13	494,883	$	22.65

	Granted		7,500	$	34.12

	Vested		184,323	$	22.68

	Forfeited		43,108	$	22.65

	Non-vested	December 31, 2013	274,952	$	22.94

Segment_Data_Tables

Segment Data (Tables)	12 Months Ended
	Dec. 31, 2013
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):


			As of and For the Year Ended December 31, 2013 (1)
	(In thousands)		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Net sales (excluding intercompany fees and sales)		$	60,237		$	847,191		$	907,428

	Operating costs and expenses:
	Cost of goods sold		764			810,600			811,364

	Operating expenses		22,903			7,399			30,302

	Segment contribution margin		$	36,570		$	29,192		65,762

	General and administrative expenses								6,856

	Depreciation and amortization								12,436

	Loss on disposal of assets								166

	Operating income								$	46,304

	Total assets		$	164,608		$	110,196		$	274,804

	Capital spending (excluding business combinations) (2)		$	6,905		$	2,493		$	9,398

	(1) The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

	(2) Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition


			As of and For the Year Ended December 31, 2012 (1)
			Predecessors
	(In thousands)		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Net sales (excluding intercompany fees and sales)		$	33,539		$	989,047		$	1,022,586

	Operating costs and expenses:
	Cost of goods sold		—			959,434			959,434

	Operating expenses		24,155			6,242			30,397

	Segment contribution margin		$	9,384		$	23,371		32,755

	General and administrative expenses								9,150

	Depreciation and amortization								10,120

	Loss on disposal of assets								9

	Operating income								$	13,476

	Total assets		$	183,204		$	100,112		$	283,316

	Capital spending (excluding business combinations) (2)		$	22,146		$	4,613		$	26,759



	(1)	The information presented is adjusted to include the results of operations of the Tyler Predecessor. Prior to the completion of the Offering and the Tyler Acquisition, our Predecessors did not record revenues for intercompany trucking, terminalling, storage and short-haul pipeline transportation services.


	(2)	Capital spending includes expenditures incurred in connection with the assets acquired in the Tyler Acquisition.



		As of and For the Year Ended December 31, 2011 (1)
		Predecessors
(In thousands)		Pipelines and Transportation (2)			Wholesale Marketing and Terminalling			Consolidated
Net sales (excluding intercompany fees and sales)		$	21,878		$	722,201		$	744,079

Operating costs and expenses:
Cost of goods sold		—			700,505			700,505

Operating expenses		15,415			4,052			19,467

Segment contribution margin		$	6,463		$	17,644		24,107

General and administrative expenses								6,483

Depreciation and amortization								6,061

Gain on disposal of assets								(2		)
Operating income								$	11,565

Total assets		$	133,257		$	89,902		$	223,159

Capital spending (excluding business combinations) (3)		$	5,905		$	1,225		$	7,130

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2013

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 was as follows: (in thousands):

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, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'
Derivative Instruments, Gain (Loss) [Table Text Block]	'
	Gains (losses) recognized associated with derivatives not designated as hedging instruments for the years ended December 31, 2013 and 2012 were as follows (in thousands):


			Year Ended December 31,
	Derivative Type	Income Statement Location	2013			2012
						Predecessors
	Interest rate derivatives	Interest expense	(106		)	—

	Commodity derivatives	Cost of goods sold	(614		)	85

		Total	$	(720	)	$	85

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	'
	The table below presents the fair value of our derivative instruments, as of December 31, 2013. As of December 31, 2012, there was a nominal amount of financial liabilities accounted for at fair value on a recurring basis (in thousands).


			December 31, 2013
	Derivative Type	Balance Sheet Location	Assets			Liabilities
	Derivatives not designated as hedging instruments:
	Interest rate derivatives	Other long term assets	$	116		$	—

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Operating Loss Carryforwards [Line Items]	'
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,
		2013			2012			2011
	Provision for federal income taxes at statutory rate	$	—		$	4,047		$	6,304

	State income taxes, net of federal tax provision	794			(58		)	255

	Valuation allowance	—			193			(1,145		)

	Permanent differences	—			300			15

	Conversion to partnership	—			(18,534		)	—

	Other items	(37		)	28			(66		)

	Income tax (benefit) expense	$	757		$	(14,024	)	$	5,363

Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	Income tax expense (benefit) is as follows (in thousands):



		Year Ended December 31,
		2013			2012			2011
	Current	$	448		$	4,738		$	9,691

	Deferred	309			(18,762		)	(4,328		)

		$	757		$	(14,024	)	$	5,363

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	Significant components of our deferred tax assets and liabilities, reported separately in the accompanying combined financial statements, as of December 31, 2013 and 2012, are as follows (in thousands):


		December 31,
		2013			2012
	Current Deferred Taxes:
	Accrued reserves	$	6		$	1

	Tank and pipeline inspection liabilities	8			2

	Contingent liabilities	—			11

	Depreciation and amortization	(2		)	—

	Total current deferred tax assets	12			14


	Non-Current Deferred Taxes:
	Depreciation and amortization	(370		)	(36		)
	Asset retirement obligations	4			1

	Tank and pipeline inspection liabilities	30			6

	Contingent liabilities	12			13

	Other	—			(1		)

	Total non-current deferred tax liabilities	(324		)	(17		)
	Total net deferred tax liabilities	$	(312	)	$	(3	)

Income_Taxes_Deferred_Tax_Liab

Income Taxes Deferred Tax Liability Not Recognized (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	Significant components of our deferred tax assets and liabilities, reported separately in the accompanying combined financial statements, as of December 31, 2013 and 2012, are as follows (in thousands):


		December 31,
		2013			2012
	Current Deferred Taxes:
	Accrued reserves	$	6		$	1

	Tank and pipeline inspection liabilities	8			2

	Contingent liabilities	—			11

	Depreciation and amortization	(2		)	—

	Total current deferred tax assets	12			14


	Non-Current Deferred Taxes:
	Depreciation and amortization	(370		)	(36		)
	Asset retirement obligations	4			1

	Tank and pipeline inspection liabilities	30			6

	Contingent liabilities	12			13

	Other	—			(1		)

	Total non-current deferred tax liabilities	(324		)	(17		)
	Total net deferred tax liabilities	$	(312	)	$	(3	)

Related_Party_Transactions_Tab

Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2013

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 .89 (3)

Refined Products Pipelines

Nov-12

40,000

0.105

SALA Gathering System

Nov-12

Crude oil gathering

14,000

$ 2.35 (3)

East Texas Crude Logistics System:

Crude Oil Pipelines

Nov-12

15-May

Crude oil transportation and storage

35,000

$ 0.42 (4)

Storage

Nov-12

N/A

$261,480/month

East Texas Marketing

Nov-12

10 (5)

Marketing products for Tyler Refinery

50,000

$ .6065/bbl(5)

Memphis Terminal

Nov-12

15-May

Dedicated terminalling services

10,000

0.52

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

0.52

Terminalling

Nov-12

5,000

0.52

Storage

Nov-12

N/A

$52,250/month

Tyler Throughput and Tankage:

Refined Products Throughput

Jul-13

16-Aug

Dedicated Terminalling and storage

50,000

0.35

Storage

Jul-13

N/A

$841,667/month

Tyler Lease and Access

Jul-13

Real property lease

N/A

$100 annually

Tyler Site Services

Jul-13

16-Aug

Shared services

N/A

$200,000 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

$63,000/month (7)

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,

2013

2012

2011

Predecessors

Revenues

77,272

43,216

34,266

Operating and maintenance expenses (1)

14,718

3,394

3,291

General and administrative expenses (2)

3,341

4,944

3,125

Selected_Quarterly_Financial_D1

Selected Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2013											Dec. 31, 2012
Selected Quarterly Financial Data [Abstract]	'											'
Quarterly Financial Information [Text Block]	'											'
	Selected Quarterly Financial Data (Unaudited)

	Quarterly financial information for the years ended December 31, 2013 and 2012 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On July 26, 2013, we acquired the Tyler Terminal and Tank Assets from Delek. Our and our Predecessors' historical data has been retrospectively adjusted to reflect the results of operations attributable to the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.



			For the Three Month Periods Ended
			31-Mar-13		30-Jun-13		30-Sep-13			31-Dec-13
	Net sales		$	210,894	$	230,141	$	243,295		$	223,097

	Operating income		$	10,309	$	9,766	$	12,887		$	13,342

	Net income		$	9,370	$	8,896	$	11,386		$	11,325

	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





			For the Three Month Periods Ended
			March 31, 2012 (1)		June 30, 2012 (1)		September 30, 2012 (1)			December 31, 2012 (1)
	Net sales		$	239,084	$	262,480	$	271,806		$	249,216

	Operating income		$	3,730	$	2,031	$	2,560		$	5,155

	Net income (loss) (3)		$	1,322	$	584	$	(544	)	$	23,456

	Limited partners' interest in net income									$	8,242

	Net income per limited partner unit: (2)
	Common (basic)									$	0.34

	Common (diluted)									$	0.34

	Subordinated - Delek (basic and diluted)									$	0.34




	(1)	The information presented includes the results of operations of the DKL Predecessor for periods presented through November 6, 2012 and of the Tyler Predecessor for all periods presented, and of the Partnership for the period beginning November 7, 2012, the date the Partnership commenced operations.

	(2)	Net income per unit is only calculated for the Partnership after the Offering as no units were outstanding prior to November 7, 2012.

	(3)	Net income for the year ended December 31, 2012 includes a one-time tax benefit of $18.5 million. The majority of the Partnership's deferred tax assets and liabilities relates to the Predecessor's conversion from a corporation to a partnership and as a result of such conversion we are not subject to federal income taxes. The conversion from a taxable corporation to a passthrough resulted in this one-time tax benefit.
Schedule of Quarterly Financial Information [Table Text Block]	'											'
	Quarterly financial information for the years ended December 31, 2013 and 2012 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On July 26, 2013, we acquired the Tyler Terminal and Tank Assets from Delek. Our and our Predecessors' historical data has been retrospectively adjusted to reflect the results of operations attributable to the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.

													For the Three Month Periods Ended
													March 31, 2012 (1)		June 30, 2012 (1)		September 30, 2012 (1)			December 31, 2012 (1)
			For the Three Month Periods Ended									Net sales	$	239,084	$	262,480	$	271,806		$	249,216
			31-Mar-13		30-Jun-13		30-Sep-13			31-Dec-13
	Net sales		$	210,894	$	230,141	$	243,295		$	223,097	Operating income	$	3,730	$	2,031	$	2,560		$	5,155

	Operating income		$	10,309	$	9,766	$	12,887		$	13,342	Net income (loss) (3)	$	1,322	$	584	$	(544	)	$	23,456

	Net income		$	9,370	$	8,896	$	11,386		$	11,325	Limited partners' interest in net income								$	8,242

	Limited partners' interest in net income		$	11,960	$	11,521	$	12,295		11,098		Net income per limited partner unit: (2)
												Common (basic)								$	0.34
	Net income per limited partner unit:
												Common (diluted)								$	0.34
	Common (basic)		$	0.5	$	0.48	$	0.51		$	0.46
												Subordinated - Delek (basic and diluted)								$	0.34
	Common (diluted)		$	0.5	$	0.47	$	0.51		$	0.46

	Subordinated - Delek (basic and diluted)		$	0.5	$	0.48	$	0.51		$	0.46

General_Details

General (Details)	0 Months Ended	1 Months Ended
General (Details)	Nov. 07, 2012	Nov. 30, 2012
Capital Unit [Line Items]	'	'
Units issued in initial public offering in November 2012	'	24,488,282
Common- Public [Member]	'	'
Capital Unit [Line Items]	'	'
Units issued in initial public offering in November 2012	9,200,000	9,200,000

Accounting_Policies_Accounts_R

Accounting Policies Accounts Receivable (Details) (Accounts Receivable [Member], Customer Concentration Risk [Member], Largest Two Customers [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Accounts Receivable [Member] \| Customer Concentration Risk [Member] \| Largest Two Customers [Member]	'	'
Concentration Risk [Line Items]	'	'
Concentration Risk, Percentage	27.20%	18.90%

Accounting_Policies_Inventory_

Accounting Policies Inventory (Details) (Two Largest Vendors [Member], Supplier Concentration Risk [Member], Inventory purchased [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Two Largest Vendors [Member] \| Supplier Concentration Risk [Member] \| Inventory purchased [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	96.10%	76.10%	96.80%

Accounting_Policies_Property_P

Accounting Policies Property, Plant and Equipment (Details)	12 Months Ended
Accounting Policies Property, Plant and Equipment (Details)	Dec. 31, 2013
Minimum [Member] \| Building and Pipeline Improvements [Member]	'
Estimated useful life (years)	'15 years
Minimum [Member] \| Pipelines and terminals [Member]	'
Estimated useful life (years)	'15 years
Minimum [Member] \| Asset retirement obligation assets [Member]	'
Estimated useful life (years)	'15 years
Minimum [Member] \| Other equipment [Member]	'
Estimated useful life (years)	'3 years
Maximum [Member] \| Building and Pipeline Improvements [Member]	'
Estimated useful life (years)	'40 years
Maximum [Member] \| Pipelines and terminals [Member]	'
Estimated useful life (years)	'40 years
Maximum [Member] \| Asset retirement obligation assets [Member]	'
Estimated useful life (years)	'50 years
Maximum [Member] \| Other equipment [Member]	'
Estimated useful life (years)	'15 years

Accounting_Policies_Intangible

Accounting Policies Intangible Assets (Details) (Supply contracts [Member])	12 Months Ended
	Dec. 31, 2013
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, 2013		Dec. 31, 2012		Dec. 31, 2011
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
Beginning balance	$3,177	[1]	$2,990		'
Liabilities settled	-400		0		'
Accretion expense	216	[2]	187	[2]	173	[2]
Ending balance	$2,993		$3,177	[1]	$2,990

[1]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical cash flows of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Accounting_Policies_Other_Nonc

Accounting Policies Other Non-current Liabilities (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Other Non-current Liabilities [Abstract]	'		'		'
Customer contract liability	'		'		$6,000,000
Amortization of unfavorable contract liability to revenue	2,623,000	[1]	668,000	[1]	0	[1]
Customer contract liability, Noncurrent	0		'		'
Tank and pipeline inspection liability, non-current	800,000		2,900,000		'
Deferred revenue for Delek's reimbursement of capital expenditures	$4,300,000		$4,500,000		'

[1]	Adjusted to include the historical cash flows of the Tyler 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, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leases [Abstract]	'	'	'
Operating Leases, Rent Expense	$0.50	$0.50	$0.30

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, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Taxes [Abstract]	'	'		'		'
Income tax expense	$100	$757	[1]	($14,024)	[1]	$5,363	[1]
Tax benefit from conversion to Partnership	'	$0		$18,534		$0

[1]	Adjusted to include the historical results of the Tyler 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
Accounting Policies Equity based compensation (Details)	Dec. 31, 2013
Accounting Policies [Abstract]	'
Awards requisite service period (years)	'5 years

Acquisitions_Details

Acquisitions (Details) (USD $)	0 Months Ended
In Millions, unless otherwise specified	Jul. 26, 2013	Jul. 26, 2013	Jul. 19, 2013	Feb. 07, 2012	Jan. 31, 2012
	Jul. 26, 2013	Tyler Terminal and Tanks [Member]	Hopewell [Member]	Big Sandy Terminal [Member]	Nettleton Pipeline [Member]
Business Acquisition [Line Items]	'	'	'	'	'
Cash paid for acquisition	$94.80	$94.80	$5.70	$5	$12.30

Acquisitions_Purchase_Price_Al

Acquisitions Purchase Price Allocation (Details) (USD $)	Oct. 24, 2013	Jul. 19, 2013	Feb. 07, 2012	Jan. 31, 2012
In Thousands, unless otherwise specified	North Little Rock Terminal [Member]	Hopewell [Member]	Big Sandy Terminal [Member]	Nettleton Pipeline [Member]
Business Acquisition [Line Items]	'	'	'	'
Property, Plant and Equipment	$4,987	$4,836	$8,258	$8,590
Intangible Assets	13	864	1,229	2,240
Goodwill (all expected to be deductible for tax purposes)	'	'	1,540	1,415
Total	$5,000	$5,700	$11,027	$12,245

Acquisitions_Pro_Forma_Infroma

Acquisitions Pro Forma Infromation (Details) (USD $)	12 Months Ended
Acquisitions Pro Forma Infromation (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
North Little Rock Terminal [Member]	'	'
Business Acquisition [Line Items]	'	'
Net sales, Actual	$200,000	'
Net income (loss), Actual	100,000	'
Net sales	908,867,000	1,024,025,000
Net income	42,268,000	26,109,000
Hopewell [Member]	'	'
Business Acquisition [Line Items]	'	'
Net sales, Actual	400,000	'
Net income (loss), Actual	-500,000	'
Net sales	908,382,000	1,023,540,000
Net income	41,291,000	25,132,000
Big Sandy Terminal [Member]	'	'
Business Acquisition [Line Items]	'	'
Net sales, Actual	1,500,000	'
Net income (loss), Actual	1,200,000	'
Nettleton Pipeline [Member]	'	'
Business Acquisition [Line Items]	'	'
Net sales, Actual	9,000,000	'
Net income (loss), Actual	7,200,000	'
Nettleton and Big Sandy [Member]	'	'
Business Acquisition [Line Items]	'	'
Net sales	'	1,022,715,000
Net income	'	$24,941,000

Acquisitions_Tyler_Acquisition

Acquisitions Tyler Acquisitions (Details) (USD $)	0 Months Ended	12 Months Ended
	Jul. 26, 2013	Dec. 31, 2013
	Jul. 26, 2013	bbl
Business Acquisition [Line Items]	'	'
Cash paid for acquisition	$94,800,000	'
Aggregate Shell Capacity (barrels)	'	2,000,000
Tyler Terminal and Tanks [Member]	'	'
Business Acquisition [Line Items]	'	'
Cash paid for acquisition	94,800,000	'
Total Throughput Capacity (bpd)	'	72,000
Historical carrying value of assets	38,300,000	'
Acquisition Related Costs	'	300,000
Net sales, Actual	'	7,500,000
Net income (loss), Actual	'	3,900,000

Acquisitions_Tyler_Terminals_a

Acquisitions 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, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Current assets:

Cash and cash equivalents

$23,452

[1],[2]

$924

[1]

$23,452

[1],[2]

$924

[1]

$23,452

[1],[2]

$35

[1]

Accounts receivable

27,725

[2]

28,976

27,725

[2]

28,976

27,725

[2]

Inventory

14,351

[2]

17,512

14,351

[2]

17,512

14,351

[2]

Deferred tax assets

Other current assets

169

[2]

341

169

[2]

341

169

[2]

Total current assets

65,711

[2]

47,765

65,711

[2]

47,765

65,711

[2]

Property, Plant and Equipment [Abstract]

Property, plant and equipment

216,048

[2]

235,588

216,048

[2]

235,588

216,048

[2]

Less: accumulated depreciation

-24,991

[2]

-36,306

-24,991

[2]

-36,306

-24,991

[2]

Property, plant and equipment, net

191,057

[2]

199,282

191,057

[2]

199,282

191,057

[2]

Goodwill

10,454

[2]

10,454

[2]

10,454

[2]

7,499

Intangible assets, net

12,430

[2]

12,258

12,430

[2]

12,258

12,430

[2]

Other non-current assets

3,664

[2]

5,045

3,664

[2]

5,045

3,664

[2]

Total assets

283,316

[2],[3]

274,804

[3]

283,316

[2],[3]

274,804

[3]

283,316

[2],[3]

223,159

[3]

Current liabilities:

Accounts payable

21,849

[2]

26,045

21,849

[2]

26,045

21,849

[2]

Accounts payable to related parties

10,148

[2]

1,513

10,148

[2]

1,513

10,148

[2]

Fuel and other taxes payable

4,650

[2]

5,700

4,650

[2]

5,700

4,650

[2]

Accrued expenses and other current liabilities

3,650

[2]

5,776

3,650

[2]

5,776

3,650

[2]

Total current liabilities

40,297

[2]

39,034

40,297

[2]

39,034

40,297

[2]

Non-current liabilities:

Revolving credit facility

90,000

[2]

164,800

90,000

[2]

164,800

90,000

[2]

Asset retirement obligations

3,177

[2]

2,993

3,177

[2]

2,993

3,177

[2]

2,990

Deferred tax liabilities

[2]

324

[2]

324

[2]

Other non-current liabilities

9,810

[2]

5,612

9,810

[2]

5,612

9,810

[2]

Total non-current liabilities

103,004

[2]

173,729

103,004

[2]

173,729

103,004

[2]

Equity:

Predecessor division equity

35,590

[2]

35,590

[2]

35,590

[2]

Common unitholders - public (9,200,000 units issued and outstanding)

178,728

[2]

183,839

178,728

[2]

183,839

178,728

[2]

Common unitholders - Delek (2,799,258 units issued and outstanding)

-127,129

[2]

-176,680

-127,129

[2]

-176,680

-127,129

[2]

Subordinated unitholders - Delek (11,999,258 units issued and outstanding)

52,875

[2]

59,386

52,875

[2]

59,386

52,875

[2]

General Partner unitholders - Delek (489,766 units issued and outstanding)

-49

[2]

-4,504

-49

[2]

-4,504

-49

[2]

Total equity

140,015

[2]

62,041

140,015

[2]

62,041

140,015

[2]

129,142

28,643

Total liabilities and equity

283,316

[2]

274,804

283,316

[2]

274,804

283,316

[2]

Combined Consolidated Statements of Income

Net sales

223,097

243,295

230,141

210,894

249,216

[4]

271,806

[4]

262,480

[4]

239,084

[4]

907,428

[3],[5]

1,022,586

[3],[5]

744,079

[3],[5]

Operating costs and expenses:

Cost of goods sold

811,364

[3],[5]

959,434

[3],[5]

700,505

[3],[5]

Operating expenses

30,302

[3],[5]

30,397

[3],[5]

19,467

[3],[5]

General and administrative expenses

6,856

[3],[5]

9,150

[3],[5]

6,483

[3],[5]

Depreciation and amortization

12,436

[1],[3]

10,120

[1],[3]

6,061

[1],[3]

Gain on disposal of assets

166

[1],[3],[5]

-2

[1],[3],[5]

Total operating costs and expenses

861,124

[5]

1,009,110

[5]

732,514

[5]

Operating income (loss)

13,342

12,887

9,766

10,309

5,155

[4]

2,560

[4]

2,031

[4]

3,730

[4]

46,304

[3],[5]

13,476

[3],[5]

11,565

[3],[5]

Interest expense, net

4,570

2,682

2,011

Net income (loss) before income tax expense

41,734

[5]

10,794

[5]

9,554

[5]

Income tax expense

100

757

[5]

-14,024

[5]

5,363

[5]

Net income (loss)

11,325

11,386

8,896

9,370

23,456

[4],[6]

-544

[4],[6]

584

[4],[6]

1,322

[4],[6]

40,977

[1],[5]

24,818

[1],[5]

4,191

[1],[5]

Less: (Loss) income attributable to Predecessors

-6,853

[5]

16,408

4,191

[5]

Net income attributable to partners

47,830

[5]

8,410

[5]

Predecessor [Member]

Current assets:

Cash and cash equivalents

Accounts receivable

Inventory

Deferred tax assets

Other current assets

Total current assets

Property, Plant and Equipment [Abstract]

Property, plant and equipment

43,748

Less: accumulated depreciation

-6,201

Property, plant and equipment, net

37,547

Goodwill

Intangible assets, net

Other non-current assets

Total assets

37,547

Current liabilities:

Accounts payable

Accounts payable to related parties

Fuel and other taxes payable

Accrued expenses and other current liabilities

Total current liabilities

Non-current liabilities:

Revolving credit facility

Asset retirement obligations

1,737

Deferred tax liabilities

Other non-current liabilities

185

Total non-current liabilities

1,922

Equity:

Predecessor division equity

35,590

Common unitholders - public (9,200,000 units issued and outstanding)

Common unitholders - Delek (2,799,258 units issued and outstanding)

Subordinated unitholders - Delek (11,999,258 units issued and outstanding)

General Partner unitholders - Delek (489,766 units issued and outstanding)

Total equity

35,590

Total liabilities and equity

37,547

Combined Consolidated Statements of Income

Net sales

Operating costs and expenses:

Cost of goods sold

Operating expenses

4,501

7,035

6,527

General and administrative expenses

602

761

688

Depreciation and amortization

1,750

1,445

1,241

Gain on disposal of assets

Total operating costs and expenses

6,853

[5]

9,241

[5]

8,456

[5]

Operating income (loss)

-6,853

[5]

-9,241

[5]

-8,456

[5]

Interest expense, net

Net income (loss) before income tax expense

-6,853

[5]

-9,241

[5]

-8,456

[5]

Income tax expense

Net income (loss)

-6,853

[5]

-9,241

[5]

-8,456

[5]

Less: (Loss) income attributable to Predecessors

-6,853

-9,241

-8,456

Net income attributable to partners

[5]

Reporting Entity [Member]

Current assets:

Cash and cash equivalents

23,452

Accounts receivable

27,725

Inventory

14,351

Deferred tax assets

Other current assets

169

Total current assets

65,711

Property, Plant and Equipment [Abstract]

Property, plant and equipment

172,300

Less: accumulated depreciation

-18,790

Property, plant and equipment, net

153,510

Goodwill

10,454

Intangible assets, net

12,430

Other non-current assets

3,664

Total assets

245,769

Current liabilities:

Accounts payable

21,849

Accounts payable to related parties

10,148

Fuel and other taxes payable

4,650

Accrued expenses and other current liabilities

3,615

Total current liabilities

40,262

Non-current liabilities:

Revolving credit facility

90,000

Asset retirement obligations

1,440

Deferred tax liabilities

Other non-current liabilities

9,625

Total non-current liabilities

101,082

Equity:

Predecessor division equity

Common unitholders - public (9,200,000 units issued and outstanding)

178,728

Common unitholders - Delek (2,799,258 units issued and outstanding)

-127,129

Subordinated unitholders - Delek (11,999,258 units issued and outstanding)

52,875

General Partner unitholders - Delek (489,766 units issued and outstanding)

-49

Total equity

104,425

Total liabilities and equity

245,769

Combined Consolidated Statements of Income

Net sales

907,428

1,022,586

744,079

Operating costs and expenses:

Cost of goods sold

811,364

959,434

700,505

Operating expenses

25,801

23,362

12,940

General and administrative expenses

6,254

8,389

5,795

Depreciation and amortization

10,686

8,675

4,820

Gain on disposal of assets

166

-2

Total operating costs and expenses

854,271

[5]

999,869

[5]

724,058

[5]

Operating income (loss)

53,157

[5]

22,717

[5]

20,021

[5]

Interest expense, net

-4,570

-2,682

-2,011

Net income (loss) before income tax expense

48,587

[5]

20,035

[5]

18,010

[5]

Income tax expense

757

-14,024

5,363

Net income (loss)

47,830

[5]

34,059

[5]

12,647

[5]

Less: (Loss) income attributable to Predecessors

25,649

12,647

Net income attributable to partners

$47,830

[5]

$8,410

[5]

[1]

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

[2]

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

[3]

The information presented includes the results of operations of the Tyler Predecessor. Prior to the completion of the Tyler Acquisition, our Predecessor did not record revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

[4]

The information presented includes the results of operations of the DKL Predecessor for periods presented through November 6, 2012 and of the Tyler Predecessor for all periods presented, and of the Partnership for the period beginning November 7, 2012, the date the Partnership commenced operations.

[5]

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

[6]

Net income for the year ended December 31, 2012 includes a one-time tax benefit of $18.5 million. The majority of the Partnership's deferred tax assets and liabilities relates to the Predecessor's conversion from a corporation to a partnership and as a result of such conversion we are not subject to federal income taxes. The conversion from a taxable corporation to a passthrough resulted in this one-time tax benefit.

Net_Income_Per_Unit_Textual_De

Net Income Per Unit Textual (Details)	9 Months Ended	12 Months Ended
Net Income Per Unit Textual (Details)	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Net Income Per Unit [Abstract]	'	'	'
General Partner's Interest	'	2.00%	2.00%
Weighted Average Number of Shares Outstanding, Basic	24,503,469	24,514,527	'

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, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net income per unit [Line Items]	'	'	'	'	'		'		'
Net income attributable to partners	'	'	'	'	$47,830	[1]	$8,410	[1]	$0	[1]
General partner's distribution	'	'	'	'	785		110		'
Limited partners' distribution	'	'	'	'	39,276		5,486		'
Earnings in excess of distributions	'	'	'	'	8,554		2,924		'
Weighted average limited partner units outstanding:	'	'	'	'	'		'		'
Common units - (basic)	'	'	'	'	12,025,249	[1]	11,999,258	[1]	'
Common units - (diluted)	'	'	'	'	12,148,774	[1]	11,999,258	[1]	'
Subordinated units - Delek (basic and diluted)	'	'	'	'	11,999,258	[1]	11,999,258	[1]	'
Net income per limited partner unit:	'	'	'	'	'		'		'
Common units - (basic)	$0.46	$0.51	$0.48	$0.50	$1.95	[1]	$0.34	[1]	'
Common units - (diluted)	$0.46	$0.51	$0.47	$0.50	$1.93	[1]	$0.34	[1]	'
Subordinated units - Delek (basic and diluted)	$0.46	$0.51	$0.48	$0.50	$1.95	[1]	$0.34	[1]	'
Limited Partner, Common Units [Member]	'	'	'	'	'		'		'
Net income per unit [Line Items]	'	'	'	'	'		'		'
Limited partners' distribution	'	'	'	'	19,292		2,688		'
Earnings in excess of distributions	'	'	'	'	4,198		1,433		'
Total earnings	'	'	'	'	23,490		4,121		'
Limited Partner, Subordinated Units [Member]	'	'	'	'	'		'		'
Net income per unit [Line Items]	'	'	'	'	'		'		'
Limited partners' distribution	'	'	'	'	19,199		2,688		'
Earnings in excess of distributions	'	'	'	'	4,184		1,433		'
Total earnings	'	'	'	'	23,383		4,121		'
General Partner [Member]	'	'	'	'	'		'		'
Net income per unit [Line Items]	'	'	'	'	'		'		'
Net income attributable to partners	'	'	'	'	957		168		'
General partner's distribution	'	'	'	'	785		110		'
Earnings in excess of distributions	'	'	'	'	172		58		'
Total earnings	'	'	'	'	$957		$168		'

[1]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Major_Customer_Details

Major Customer (Details) (Customer Concentration Risk [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Delek US [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Revenues	'	$236.70	$27.80
Susser [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Revenues	$160.80	$178.90	$154.60
Sales Revenue, Segment [Member] \| Delek US [Member] \| Wholesale Marketing and Terminalling [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	'	20.90%	'
Sales Revenue, Segment [Member] \| Delek US [Member] \| Pipelines and Transportation [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	84.20%	88.70%	'
Sales Revenue, Segment [Member] \| Susser [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	17.70%	'	'
Sales Revenue, Segment [Member] \| Susser [Member] \| Wholesale Marketing and Terminalling [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	19.00%	17.50%	'
Segment Gross Margin [Member] \| Delek US [Member] \| Wholesale Marketing and Terminalling [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	72.20%	51.20%	57.30%
Segment Gross Margin [Member] \| Delek US [Member] \| Pipelines and terminals [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	84.00%	88.70%	46.00%

Inventory_Narrative_Details

Inventory Narrative (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Inventory [Abstract]	'	'
Carrying value of inventory	$17,512	$14,351	[1]

[1]	Includes the historical balances of the Tyler 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, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	$235,588	$216,048	[1]
Less: accumulated depreciation	-36,306	-24,991	[1]
Property, plant and equipment, net	199,282	191,057	[1]
Depreciation expense	11,373	9,056
Land and Land Improvements [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,931	1,084
Building and Building Improvements [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	944	923
Pipelines and terminals [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	205,866	175,456
Asset retirement obligation assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,999	1,998
Other equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	2,219	1,557
Construction in process [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	22,629	35,030
Wholesale Marketing and Terminalling [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	60,765	47,852
Less: accumulated depreciation	-14,274	-11,349
Property, plant and equipment, net	46,491	36,503
Depreciation expense	2,617	2,285
Pipelines and Transportation [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	174,823	168,196
Less: accumulated depreciation	-22,032	-13,642
Property, plant and equipment, net	152,791	154,554
Depreciation expense	$8,756	$6,771

[1]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Goodwill_Details

Goodwill (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Goodwill [Roll Forward]	'		'		'
Beginning balance	$10,454	[1]	$7,499		$7,499
Goodwill Impairment	0		0		0
Goodwill acquired through the business combinations of Nettleton and Big Sandy	'		2,955		'
Ending balance	$10,454		$10,454	[1]	$7,499

[1]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Other_Intangibles_Details

Other Intangibles (Details) (USD $)	12 Months Ended
Other Intangibles (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011
Other Intangible Assets [Line Items]	'	'		'
Accumulated Amortization	($7,885,000)	($6,822,000)		'
Intangible assets, gross	20,143,000	19,252,000		'
Intangible assets, net	12,258,000	12,430,000	[1]	'
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	-7,885,000	-6,822,000		'
Intangible assets, net	4,342,000	5,405,000		'
Amortization of Intangible Assets	1,100,000	1,100,000		1,100,000
Amortization Expense, 2014	1,100,000	'		'
Amortization Expense, 2015	1,100,000	'		'
Amortization Expense, 2016	1,100,000	'		'
Amortization Expense, 2017	1,100,000	'		'
Rights-of-Way [Member]	'	'		'
Other Intangible Assets [Line Items]	'	'		'
Rights-of-way assets	$7,916,000	$7,025,000		'

[1]	Includes the historical balances of the Tyler 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) (USD $)	12 Months Ended
	Dec. 31, 2013	Jul. 09, 2013	Nov. 07, 2012
Debt Instrument [Line Items]	'	'	'
Long-term Obligations	$164,800,000	'	'
Letters of Credit	12,000,000	'	'
Available borrowing capacity	223,200,000	'	'
Revolving Credit Facility [Member] \| Fifth Third Bank [Member] \| Line of Credit [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Maximum Borrowing Capacity	'	400,000,000	175,000,000
Maximum Borrowing Capacity under Accordion Feature	'	450,000,000	'
Weighted Average Interest Rate	2.50%	'	'
Unused Capacity, Commitment Fee Percentage	0.40%	'	'
Intercompany Note Payable	$102,000,000	'	'

LongTerm_Obligations_and_Short3

Long-Term Obligations and Short-Term Note Payable Maturities of Long-term debt (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Maturities of Long-term Debt [Abstract]	'
2014	$0
2015	0
2016	0
2017	164,800
2018	0
Thereafter	0
Long-term Obligations	$164,800

Equity_Details

Equity (Details)	12 Months Ended
Equity (Details)	Dec. 31, 2013	Dec. 31, 2012
Equity [Abstract]	'	'
Common limited partner units	9,353,240	9,200,000
Delek's limited partner ownership interest	60.00%	'
Common unitholders - Delek	2,799,258	2,799,258
Subordinated limited partner units	11,999,258	11,999,258
Delek's ownership interest in General Partner	96.60%	'
General Partner's Interest	2.00%	2.00%
General Partner's units	492,893	489,766

Equity_Units_Rollforward_Detai

Equity Units Rollforward (Details)	0 Months Ended	1 Months Ended	12 Months Ended
Equity Units Rollforward (Details)	Nov. 07, 2012	Nov. 30, 2012	Dec. 31, 2013
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Units issued in initial public offering in November 2012	'	24,488,282	'
Balance at December 31, 2012	'	'	24,488,282
GP units issued to maintain 2% interest	'	'	3,127
Unit-based compensation awards	'	'	153,240	[1]
Balance at December 31, 2013	'	'	24,644,649
Units Paid For Tax Withholding For Unit-Based Compensation	'	'	31,083
Common- Public [Member]	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Units issued in initial public offering in November 2012	9,200,000	9,200,000	'
Balance at December 31, 2012	'	'	9,200,000
Unit-based compensation awards	'	'	153,240	[1]
Balance at December 31, 2013	'	'	9,353,240
Common- Delek [Member]	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Units issued in initial public offering in November 2012	'	2,799,258	'
Balance at December 31, 2012	'	'	2,799,258
Unit-based compensation awards	'	'	0	[1]
Balance at December 31, 2013	'	'	2,799,258
Subordinated [Member]	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Units issued in initial public offering in November 2012	'	11,999,258	'
Balance at December 31, 2012	'	'	11,999,258
Unit-based compensation awards	'	'	0	[1]
Balance at December 31, 2013	'	'	11,999,258
General Partner [Member]	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Units issued in initial public offering in November 2012	'	489,766	'
Balance at December 31, 2012	'	'	489,766
GP units issued to maintain 2% interest	'	'	3,127
Unit-based compensation awards	'	'	0	[1]
Balance at December 31, 2013	'	'	492,893

[1]	Unit-based compensation awards are presented net of 31,083 units withheld for taxes.

Equity_Net_income_applicable_t

Equity Net income applicable to partners (Details) (USD $)	3 Months Ended					12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Schedule of Allocation of Net Income to General Partner [Line Items]	'	'	'	'	'	'		'		'
Net income attributable to partners	'	'	'	'	'	$47,830	[1]	$8,410	[1]	$0	[1]
Limited partners' interest in net income	11,098	12,295	11,521	11,960	8,242	46,873	[1]	8,242	[1]	'
General Partner's Interest	'	'	'	'	'	2.00%		2.00%		'
Limited Partner Subordinated [Member]	'	'	'	'	'	'		'		'
Schedule of Allocation of Net Income to General Partner [Line Items]	'	'	'	'	'	'		'		'
Limited partners' interest in net income	'	'	'	'	'	23,383		4,121		'
Limited Partner, Common [Member]	'	'	'	'	'	'		'		'
Schedule of Allocation of Net Income to General Partner [Line Items]	'	'	'	'	'	'		'		'
Limited partners' interest in net income	'	'	'	'	'	23,490		4,121		'
Limited Partner [Member]	'	'	'	'	'	'		'		'
Schedule of Allocation of Net Income to General Partner [Line Items]	'	'	'	'	'	'		'		'
Limited partners' interest in net income	'	'	'	'	'	46,873		8,242		'
General Partner [Member]	'	'	'	'	'	'		'		'
Schedule of Allocation of Net Income to General Partner [Line Items]	'	'	'	'	'	'		'		'
Less: General partner's allocated interest in net income	'	'	'	'	'	$957		$168		'

[1]	Adjusted to include the historical results of the Tyler 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, 2013	Dec. 31, 2012
Incentive Distribution Made to Member or Limited Partner [Line Items]	'	'
General Partner's Interest	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 [Member]	'	'
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 [Member]	'	'
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 [Member]	'	'
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 [Member]	'	'
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 [Member]	'	'
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

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Nov. 14, 2013

Aug. 13, 2013

15-May-13

Feb. 14, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 13, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Subsequent Event [Member]

Limited Partner, Common Units [Member]

General Partner [Member]

Limited Partner, Subordinated Units [Member]

Distribution Made to Limited Partner [Line Items]

Quarterly cash distribution (dollars per unit)

$0.41

$0.40

$0.39

$0.22

[1]

$0.42

Distribution Made To Member Or Limited Partner Distributions Paid Annualized Per Unit

$1.62

$1.58

$1.54

$0.90

[1]

$1.66

Distribution Made to Limited Partner, Cash Distributions Paid

$9,933

$9,687

$9,428

$5,486

[1]

$3,944

[2]

$116,535

[2]

$10,228

Distributions to unitholders and general partner related to assets acquired in the initial public offering

785

110

785

110

Limited Partners' Capital Account, Distribution Amount

$39,276

$5,486

$19,292

$2,688

$19,199

$2,688

Cash distributions per unit

$1.60

[3]

$0.22

[3]

Footnote [Abstract]

Minimum quarterly cash distribution

$0.38

Annualized minimum quarterly distributions

$1.50

[1]

The quarterly cash distribution for the three months ended December 31, 2012 was calculated as the minimum quarterly cash distribution of $0.375 per unit per quarter, or $1.50 per unit on an annualized basis, prorated for the period beginning November 7, 2012, the date the Partnership commenced operations.

[2]

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

[3]

Adjusted to include the historical results of the Tyler 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
Equity Based Compensation Narrative (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Equity Based Compensation [Abstract]	'		'		'
Number of units authorized	612,207		'		'
Unit-based compensation expense	$500,000		'		'
Total fair value of vested units	4,200,000		0		0
Unrecognized compensation costs	800,000		0		'
Unrecognized compensation costs, weighted-average period for recognition	'4 years 0 months 0 days		'		'
Share-based compensation, predecessor	0	[1]	92,000	[1]	64,000	[1]
Share based compensation, predecessor expense recognized for allocated related party services	'		$500,000		$500,000

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

Equity_Based_Compensation_Unit

Equity Based Compensation Unit Award Activity Summary (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Unit Award Activity [Roll Forward]	'
Non-vested, number of phantom units, January 1, 2013	494,883
Granted, number of phantom units	7,500
Vested, number of phantom units	184,323
Forfeited, number of phantom units	43,108
Non-vested, number of phantom units, December 31, 2013	274,952
Unit award activity, Weighted Average Grant Date Fair Value [Roll Forward]	'
Non-vested, weighted-average grant price, January 1, 2013	$22.65
Granted, weighted-average grant price	$34.12
Vested, weighted average grant price	$22.68
Forfeitures, weighted-average grant price	$22.65
Non-vested, weighted-average grant price, December 31, 2013	$22.94

Segment_Data_Details

Segment Data (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

Net sales (excluding intercompany fees and sales)

$223,097

$243,295

$230,141

$210,894

$249,216

[1]

$271,806

[1]

$262,480

[1]

$239,084

[1]

$907,428

[2],[3]

$1,022,586

[2],[3]

$744,079

[2],[3]

Operating Costs and Expenses [Abstract]

Cost of goods sold

811,364

[2],[3]

959,434

[2],[3]

700,505

[2],[3]

Operating expenses

30,302

[2],[3]

30,397

[2],[3]

19,467

[2],[3]

Segment Contribution Margin

65,762

[2]

32,755

[2]

24,107

[2]

General and administrative expenses

6,856

[2],[3]

9,150

[2],[3]

6,483

[2],[3]

Depreciation and amortization

12,436

[2],[4]

10,120

[2],[4]

6,061

[2],[4]

Loss (gain) on asset disposals

166

[2],[3],[4]

-2

[2],[3],[4]

Operating income

13,342

12,887

9,766

10,309

5,155

[1]

2,560

[1]

2,031

[1]

3,730

[1]

46,304

[2],[3]

13,476

[2],[3]

11,565

[2],[3]

Total assets

274,804

[2]

283,316

[2],[5]

274,804

[2]

283,316

[2],[5]

223,159

[2]

Capital spending (excluding business combinations)

9,398

[2],[4],[6]

26,759

[2],[4],[6]

7,130

[2],[4],[6]

Pipelines and Transportation [Member]

Segment Reporting Information [Line Items]

Net sales (excluding intercompany fees and sales)

60,237

[2]

33,539

[2]

21,878

[2],[7]

Operating Costs and Expenses [Abstract]

Cost of goods sold

764

[2]

[2],[7]

Operating expenses

22,903

[2]

24,155

[2]

15,415

[2],[7]

Segment Contribution Margin

36,570

[2]

9,384

[2]

6,463

[2],[7]

Total assets

164,608

[2]

183,204

[2]

164,608

[2]

183,204

[2]

133,257

[2],[7]

Capital spending (excluding business combinations)

6,905

[2],[6]

22,146

[2],[6]

5,905

[2],[6],[7]

Wholesale Marketing and Terminalling [Member]

Segment Reporting Information [Line Items]

Net sales (excluding intercompany fees and sales)

847,191

[2]

989,047

[2]

722,201

[2]

Operating Costs and Expenses [Abstract]

Cost of goods sold

810,600

[2]

959,434

[2]

700,505

[2]

Operating expenses

7,399

[2]

6,242

[2]

4,052

[2]

Segment Contribution Margin

29,192

[2]

23,371

[2]

17,644

[2]

Total assets

110,196

[2]

100,112

[2]

110,196

[2]

100,112

[2]

89,902

[2]

Capital spending (excluding business combinations)

$2,493

[2],[6]

$4,613

[2],[6]

$1,225

[2],[6]

[1]

[2]

[3]

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

[4]

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

[5]

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

[6]

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

[7]

The operating results presented are for the 247 days and 12 days, respectively, Delek operated the El Dorado Refinery and the Paline Pipeline System in 2011.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Cash collateral	$0
Fair Value, Measurements, Recurring [Member] \| Interest rate derivatives [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Derivative Asset	116,000
Fair Value, Measurements, Recurring [Member] \| Interest rate derivatives [Member] \| Level 1 [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Derivative Asset	0
Fair Value, Measurements, Recurring [Member] \| Interest rate derivatives [Member] \| Level 2 [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Derivative Asset	116,000
Fair Value, Measurements, Recurring [Member] \| Interest rate derivatives [Member] \| Level 3 [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Derivative Asset	$0

Derivative_Instruments_Details

Derivative Instruments (Details) (USD $)	12 Months Ended
Derivative Instruments (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Unrealized Gain (Loss) on Derivatives	$0	'
Notional Amount	45,000,000	'
Gain (Loss) Recognized in Income	-720,000	85,000
Other long term assets [Member] \| Derivatives not designated as hedging instrument [Member] \| Interest rate derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Assets	116,000	'
Liabilities	0	'
Interest expense [Member] \| Derivatives not designated as hedging instrument [Member] \| Interest rate derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Gain (Loss) Recognized in Income	-106,000	0
Cost of goods sold [Member] \| Derivatives not designated as hedging instrument [Member] \| Commodity derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Gain (Loss) Recognized in Income	($614,000)	$85,000

Income_Taxes_Narrative_Details

Income Taxes Narrative (Details) (USD $)	2 Months Ended	12 Months Ended
Income Taxes Narrative (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Taxes [Abstract]	'	'		'		'
Accrued Income Taxes, Current	'	$400,000		'		'
Income tax expense (benefit)	100,000	757,000	[1]	-14,024,000	[1]	5,363,000	[1]
Tax benefit from conversion to Partnership	'	0		18,534,000		0
Deferred Tax Liabilities, Gross, Noncurrent	'	400,000		'		'
Unrecognized Tax Benefits	$0	$0		$0		$0

[1]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Income_Taxes_Components_of_Def

Income Taxes Components of Deferred Tax Assets and Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]	'	'
Accrued reserves	$6	$1
Tank and pipeline inspection liabilities	8	2
Contingent liabilities	0	11
Depreciation and amortization	-2	0
Total current deferred tax assets	12	14	[1]
Depreciation and amortization	-370	-36
Asset retirement obligations	4	1
Tank and pipeline inspection liabilities	30	6
Contingent liabilities	12	13
Other	0	-1
Total non-current deferred tax liabilities	-324	-17	[1]
Total net deferred tax liabilities	($312)	($3)

[1]	Includes the historical balances of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

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, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'		'		'
Provision for federal income taxes at statutory rate	'	$0		$4,047		$6,304
State income taxes, net of federal tax provision	'	794		-58		255
Valuation allowance	'	0		193		-1,145
Permanent differences	'	0		300		15
Conversion to partnership	'	0		-18,534		0
Other items	'	-37		28		-66
Income tax expense (benefit)	$100	$757	[1]	($14,024)	[1]	$5,363	[1]

[1]	Adjusted to include the historical results of the Tyler 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, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'		'		'
Current	'	$448		$4,738		$9,691
Deferred	'	309	[1]	-18,762	[1]	-4,328	[1]
Income tax expense (benefit)	$100	$757	[2]	($14,024)	[2]	$5,363	[2]

[1]	Adjusted to include the historical cash flows of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Tyler Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Commitments_and_Contingencies_1

Commitments and Contingencies Contracts and Agreements (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Long-term Purchase Commitment [Line Items]	'
Maximum Exposure for Environmental Remediation under Omnibus Agreement	$0.25
Abilene Contract [Member]	'
Long-term Purchase Commitment [Line Items]	'
Maximum Purchases under Supply Contract	20,350
East Houston Contract [Member]	'
Long-term Purchase Commitment [Line Items]	'
Maximum Purchases under Supply Contract	7,000

Commitments_and_Contingencies_2

Commitments and Contingencies Letters of Credit (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified	Dec. 31, 2013
Letters of Credit [Abstract]	'
Letters of Credit	$12

Commitments_and_Contingencies_3

Commitments and Contingencies Operating Leases (Details) (USD $)	12 Months Ended			0 Months Ended	1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jul. 26, 2013	Jul. 31, 2013
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Tyler Lease and Access Agreement [Member]	Tyler Lease and Access Agreement [Member]
Related Party Transaction [Line Items]	'	'	'	'	'
Related party transaction, annual lease payment	'	'	'	$100	$100
Lessee Leasing Arrangements, Operating Leases, Term of Contract	'	'	'	'50 years	'
Operating Leases, Rent Expense	$500,000	$500,000	$300,000	'	'

Related_Party_Transactions_Com

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

1 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Nov. 30, 2012

Nov. 07, 2012

Nov. 30, 2012

Jul. 31, 2013

Jul. 26, 2013

Jul. 31, 2013

Oct. 31, 2013

Nov. 07, 2012

Nov. 30, 2012

Lion Pipeline and Storage Facilities Agreement [Member]

East Texas Marketing Agreement [Member]

Terminalling Services Agreements [Member]

Tyler Terminal Throughput and Tankage Agreement [Member]

Tyler Lease and Access Agreement [Member]

Tyler Site Services Agreement [Member]

North Little Rock Terminal [Member]

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

Crude Oil Pipeline [Member]

Refined Product Pipeline [Member]

SALA Gathering System member [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Memphis Terminal [Member]

Big Sandy Terminal [Member]

Big Sandy Refined Products Transportation [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Crude Oil Pipeline [Member]

Memphis Terminal [Member]

Big Sandy Terminal [Member]

Big Sandy Refined Products Transportation [Member]

Memphis Terminal [Member]

Big Sandy Terminal [Member]

Big Sandy Refined Products Transportation [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

'5 years

'15 years

[1]

'10 years

[2]

'5 years

[3]

'5 years

[3]

'15 years

[3]

'15 years

[3]

'8 years

'16 years

'50 years

'8 years

'16 years

'8 years

'16 years

'5 years

'15 years

Related Party Annual Service Fee

$200,000

Related party transaction, annual lease payment

100

Minimum Monthly Storage Fee Revenue, Amount

52,250

[3]

841,667

63,000

[4]

261,480

Minimum Throughput Commitment (bpd)

46,000

[5]

40,000

14,000

50,000

10,000

5,000

[3]

5,000

[3]

50,000

8,100

35,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.89

[6]

0.105

2.35

[6]

0.6065

0.52

[3]

0.52

[3]

0.35

0.23

[4]

0.42

[7]

Throughput Volume Subject to Additional Fee (bpd)

50,000

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

0.638

Profit Sharing Incentive Fee Revenue, Quarterly Amount

$175,000

$500,000

[1]

Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof.

[2]

[3]

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. Even though the Big Sandy Terminal was not operational for a majority of the year ended DecemberB 31, 2013, as the pipeline required maintenance in order to return it to service, Delek paid to us the minimum terminal and storage fees for the Big Sandy Terminal pursuant to the agreement above. The terminal was available for use by Delek, beginning in the fourth quarter 2013.

[4]

[5]

Excludes volumes gathered on the SALA Gathering System

[6]

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

[7]

For any volumes in excess of 50,000 bpd, the throughput fee will be $0.638/bbl.

Related_Party_Transactions_Omn

Related Party Transactions Omnibus Agreement (Details) (USD $)	0 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Jul. 26, 2013	Nov. 07, 2012	Dec. 31, 2013
Related Party Transaction [Line Items]	'	'	'
Indemnification Deductible	'	'	$0.90
Omnibus Agreement [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Omnibus Agreement Annual Amount	3	2.7	'
Payment for Management Fee	'	'	3.7
Annual Maximum Tank Repair and Maintenance Expense	'	0.5	'
Maximum Non-Discretionary Maintenance Capital Expenditures	1.4	0.4	'
Omnibus Agreement [Member] \| General and administrative services [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Payment for Management Fee	'	'	2.8
Omnibus Agreement [Member] \| Insurance coverage [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Payment for Management Fee	'	'	$0.90

Related_Party_Transactions_Ope

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

Related_Party_Transactions_Oth

Related Party Transactions Other Agreements (Details) (Paline Pipeline System Capacity Reservation Agreement [Member], USD $)	3 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Minimum [Member]	Maximum [Member]
Related Party Transaction [Line Items]	'	'	'	'	'
Monthly Capacity Fee Revenue Amount	'	'	'	$450,000	$529,250
Throughput volume subject to agreement	'	'	30,000	'	'
Monthly Capacity Fee Revenue, Amount Received	$229,000	$529,250	'	'	'

Related_Party_Transactions_Sum

Related Party Transactions Summary of Transactions (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Nov. 14, 2013

Aug. 13, 2013

15-May-13

Feb. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 13, 2014

Delek US [Member]

Tyler Predecessor [Member]

Subsequent Event [Member]

Related Party Transaction [Line Items]

Revenue

$77,272

$43,216

$34,266

Operating and maintenance expenses

14,718

[1]

3,394

[1]

3,291

[1]

1,400

[1]

2,700

[1]

2,700

General and administrative expenses

$3,341

[2]

$4,944

[2]

$3,125

[2]

$500

[1]

$800

[1]

$700

[1]

Quarterly cash distribution (dollars per unit)

$0.41

$0.40

$0.39

$0.22

[3]

$0.42

[1]

Operating and maintenance expenses include costs allocated to the Tyler Predecessor for operating support provided to the Tyler Predecessor by Delek Refining, including certain labor related costs, property and liability insurance costs and certain other operating expenses. The costs that were allocated to us were $1.4 million for the year ended DecemberB 31, 2013, and $2.7 million, for each of the years ended DecemberB 31, 2012 and 2011.

[2]

[3]

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, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Selected Quarterly Financial Data [Abstract]

Net sales

$223,097

$243,295

$230,141

$210,894

$249,216

[1]

$271,806

[1]

$262,480

[1]

$239,084

[1]

$907,428

[2],[3]

$1,022,586

[2],[3]

$744,079

[2],[3]

Operating income

13,342

12,887

9,766

10,309

5,155

[1]

2,560

[1]

2,031

[1]

3,730

[1]

46,304

[2],[3]

13,476

[2],[3]

11,565

[2],[3]

Net income

11,325

11,386

8,896

9,370

23,456

[1],[4]

-544

[1],[4]

584

[1],[4]

1,322

[1],[4]

40,977

[3],[5]

24,818

[3],[5]

4,191

[3],[5]

Limited partners' interest in net income

11,098

12,295

11,521

11,960

8,242

46,873

[3]

8,242

[3]

Common (basic)

$0.46

$0.51

$0.48

$0.50

$1.95

[3]

$0.34

[3]

Common (diluted)

$0.46

$0.51

$0.47

$0.50

$1.93

[3]

$0.34

[3]

Subordinated - Delek (basic and diluted)

$0.46

$0.51

$0.48

$0.50

$1.95

[3]

$0.34

[3]

Tax benefit from conversion to Partnership

$18,534

[1]

[2]

[3]

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

[4]

[5]

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

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

In Millions, except Per Share data, unless otherwise specified

Nov. 14, 2013

Aug. 13, 2013

Jul. 26, 2013

15-May-13

Feb. 14, 2013

Dec. 31, 2013

Feb. 13, 2014

Feb. 10, 2014

Jul. 26, 2013

Nov. 07, 2012

Feb. 10, 2014

bbl

Subsequent Event [Member]

El Dorado Terminal and Tanks [Member]

El Dorado Throughput and Tankage Agreement [Member]

Omnibus Agreement [Member]

El Dorado Lease and Access Agreement [Member]

El Dorado Site Services Agreement [Member]

Subsequent Event [Member]

bbl

Subsequent Event [Line Items]

Quarterly cash distribution (dollars per unit)

$0.41

$0.40

$0.39

$0.22

[1]

$0.42

Cash paid for acquisition

$94.80

$95.90

Total Throughput Capacity (bpd)

26,700

Throughput, Actual (bpd)

12,649

Number of Storage Tanks

158

Aggregate Shell Capacity (barrels)

2,000,000

2,500,000

Term Of Agreement (years)

'8 years

'50 years

Omnibus Agreement Annual Amount

$2.70

$3.30

[1]