Delek Logistics Partners (DKL) 10-K 1 Mar 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Feb. 22, 2019	Jun. 30, 2018
Entity Information [Line Items]
Entity Registrant Name	Delek Logistics Partners, LP
Entity Central Index Key	1,552,797
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Current Reporting Status	Yes
Entity Public Float			$ 241,075,345
Common Units
Entity Information [Line Items]
Common Stock, Shares, Outstanding		24,407,405
General Partner
Entity Information [Line Items]
Common Stock, Shares, Outstanding		498,110

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 4,522	$ 4,675
Accounts receivable	21,586	23,013
Accounts receivable from related parties	0	1,124
Inventory	5,491	20,855
Other current assets	969	783
Total current assets	32,568	50,450
Property, plant and equipment:
Property, plant and equipment	452,746	367,179
Less: accumulated depreciation	(140,184)	(112,111)
Property, plant and equipment, net	312,562	255,068
Equity method investments	104,770	106,465
Goodwill	12,203	12,203
Intangible assets, net	154,038	15,917
Other non-current assets	8,452	3,427
Total assets	624,593	443,530
Current liabilities:
Accounts payable	14,226	19,147
Accounts payable to related parties	7,833	0
Excise and other taxes payable	4,069	4,700
Tank inspection liabilities	902	902
Pipeline release liabilities	4,419	1,000
Accrued expenses and other current liabilities	5,056	6,033
Total current liabilities	36,505	31,782
Non-current liabilities:
Long-term debt	700,430	422,649
Asset retirement obligations	5,191	4,064
Other non-current liabilities	17,290	14,260
Total non-current liabilities	722,911	440,973
Deficit:
Total deficit	(134,823)	(29,225)
Total liabilities and deficit	624,593	443,530
General partner - 498,038 units issued and outstanding at December 31, 2018 (497,604 at December 31, 2017)
Deficit:
Total deficit	(6,486)	(6,397)
Common unitholders - public; 9,109,807 units issued and outstanding at December 31, 2018 (9,088,587 at December 31, 2017) | Limited Partner
Deficit:
Total deficit	171,023	174,378
Common unitholders - Delek Holdings; 15,294,046 units issued and outstanding at December 31, 2018 (15,294,046 at December 31, 2017) | Limited Partner
Deficit:
Total deficit	$ (299,360)	$ (197,206)

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - shares	Dec. 31, 2018	Dec. 31, 2017
Common unitholders, issued (in units)	24,901,891	24,880,237
Common - Public
Common unitholders, outstanding (in units)	9,109,807
Common - Delek Holdings
Common unitholders, outstanding (in units)	15,294,046
Limited Partner | Common - Public
Common unitholders, issued (in units)	9,109,807	9,088,587
Common unitholders, outstanding (in units)	9,109,807	9,088,587
Limited Partner | Common - Delek Holdings
Common unitholders, issued (in units)	15,294,046	15,294,046
Common unitholders, outstanding (in units)	15,294,046	15,294,046
General Partner
Common unitholders, issued (in units)	498,038	497,604
General partner, issued (in units)	498,038	497,604
General partner, outstanding (in units)	498,038	497,604

Consolidated Statements of Inco

Consolidated Statements of Income and Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net revenues:
Affiliate	[1]	$ 240,809	$ 156,280	$ 149,564
Third party		416,800	381,795	298,495
Net revenues		657,609	538,075	448,059
Cost of sales:
Cost of materials and other		429,061	372,890	302,158
Operating expenses (excluding depreciation and amortization presented below)		55,924	40,154	34,896
Depreciation and amortization		24,108	19,026	17,897
Total cost of sales		509,093	432,070	354,951
Operating expenses related to wholesale business (excluding depreciation and amortization presented below)		2,820	3,120	2,302
General and administrative expenses		17,166	11,840	10,256
Depreciation and amortization		1,882	2,888	2,916
Loss (gain) on asset disposals		891	(20)	(16)
Total operating costs and expenses		531,852	449,898	370,409
Operating income		125,757	88,177	77,650
Interest expense, net		41,263	23,944	13,587
(Income) loss from equity method investments		(6,230)	(4,953)	1,178
Other expense (income), net		8	(1)	0
Total non-operating expenses, net		35,041	18,990	14,765
Income before income tax expense (benefit)		90,716	69,187	62,885
Income tax expense (benefit)		534	(222)	81
Net income		90,182	69,409	62,804
Net income attributable to partners		90,182	69,409	62,804
Comprehensive income attributable to partners		90,182	69,409	62,804
Less: General partner's interest in net income, including incentive distribution rights		25,543	18,429	12,193
Limited partners' interest in net income		$ 64,639	$ 50,980	$ 50,611
Weighted average limited partner units outstanding (2):
Cash distributions per limited partner unit (in usd per unit)		$ 3.120	$ 2.835	$ 2.575
Common Units
Common units - (basic)
Common units - (basic) (in usd per unit)		2.65	2.09	2.08
Common units - (diluted) (in usd per unit)		$ 2.65	$ 2.09	$ 2.07
Weighted average limited partner units outstanding (2):
Common units - (basic) (in units)	[2]	24,390,286	24,348,063	22,490,264
Common units - (diluted) (in units)	[2]	24,396,881	24,376,972	22,558,717
Subordinated- Delek
Common units - (basic)
Subordinated units - Delek Holdings (basic and diluted) (in usd per unit)		$ 0	$ 0	$ 2.19
Weighted average limited partner units outstanding (2):
Subordinated units - Delek Holdings (basic and diluted) (in units)	[2]	0	0	1,803,167
[1]	See Note 4 for a description of our material affiliate revenue transactions.
[2]	We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflect the conversion of the subordinated units to common units on February 25, 2016. See Notes 6 and 12

Consolidated Statements of Part

Consolidated Statements of Partners' Equity (Deficit) - USD ($) $ in Thousands		Total	Limited PartnerCommon - Public	Limited PartnerCommon - Delek Holdings	Limited PartnerSubordinated- Delek	General Partner	Big Spring Logistic Assets	Big Spring Logistic AssetsLimited PartnerCommon - Delek Holdings	Big Spring Logistic AssetsGeneral Partner
Beginning balance at Dec. 31, 2015		$ (11,018)	$ 198,401	$ (280,828)	$ 78,601	$ (7,192)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cash distributions	[1]	(70,865)	(23,847)	(25,271)	(11,503)	(10,244)
Sponsorship contribution of fixed assets		5,167		5,063		104
Net income attributable to partners		62,804	19,667	27,002	3,942	12,193
Unit-based compensation		599	664	1,046		(1,111)
Subordinated unit conversion		0		71,040	(71,040)
Distributions to unitholders and general partner related to acquisitions		0	(6,872)	6,872
Net income attributable to partners		29				29
Ending balance at Dec. 31, 2016		(13,284)	188,013	(195,076)	0	(6,221)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distribution equivalents on vested phantom units		300
Cash distributions	[2]	(86,159)	(25,978)	(42,490)		(17,691)
Sponsorship contribution of fixed assets		67		65		2
Net income attributable to partners		69,409	19,015	31,965		18,429
Unit-based compensation		721	619	1,039		(937)
Distributions to unitholders and general partner related to acquisitions		0	(7,291)	7,291
Net income attributable to partners		21				21
Ending balance at Dec. 31, 2017		(29,225)	174,378	(197,206)	0	(6,397)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distribution equivalents on vested phantom units		500
Distributions to Delek Holdings for Big Spring Asset Acquisition							$ 98,798	$ 96,822	$ 1,976
Cash distributions	[3]	(97,836)	(27,721)	(46,417)		(23,698)
GP Units Issued to maintain 2% interest		26				26
Sponsorship contribution of fixed assets		154		151		3
Net income attributable to partners		90,182	24,119	40,520		25,543
Unit-based compensation		674	247	414		13
Ending balance at Dec. 31, 2018		(134,823)	$ 171,023	$ (299,360)	$ 0	$ (6,486)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distribution equivalents on vested phantom units		$ 100
[1]	Cash distributions include $0.3
[2]	Cash distributions include $0.5
[3]	Cash distributions include $0.1 million related to distribution equivalents on vested phantom units

Consolidated Statements of Pa_2

Consolidated Statements of Partners' Equity (Deficit) (Parenthetical)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Partners' Capital [Abstract]
General partner's ownership interest	2.00%	2.00%	2.00%

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash flows from operating activities:
Net income	$ 90,182	$ 69,409	$ 62,804
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	25,990	21,914	20,813
Amortization of customer contract intangible assets	6,009	0	0
Amortization of deferred revenue	(1,497)	(1,234)	(1,085)
Amortization of deferred financing costs and debt discount	2,577	2,048	1,460
Accretion of asset retirement obligations	359	292	266
Loss (gain) on asset disposals	891	(20)	(16)
Deferred income taxes	152	(111)	(173)
(Income) loss from equity method investments	(6,230)	(4,953)	1,178
Dividends from equity method investments	6,936	2,346	0
Unit-based compensation expense	674	721	599
Changes in assets and liabilities:
Accounts receivable	1,427	(3,811)	15,847
Inventories and other current assets	15,178	(11,692)	2,045
Accounts payable and other current liabilities	(1,747)	10,859	3,551
Accounts receivable/payable to related parties	9,038	1,682	(6,983)
Non-current assets and liabilities, net	(1,986)	(500)	401
Net cash provided by operating activities	147,953	86,950	100,707
Cash flows from investing activities:
Asset acquisitions, net of assumed ARO liabilities	(72,380)	(6,443)	0
Purchases of property, plant and equipment	(12,931)	(18,184)	(11,287)
Proceeds from sales of property, plant and equipment	502	46	175
Purchases of intangible assets	(144,219)	(2,560)	0
Distributions from equity method investments	1,162	753	0
Equity method investment contributions	(173)	(3,531)	(61,580)
Net cash used in investing activities	(228,039)	(29,919)	(72,692)
Cash flows from financing activities:
Proceeds from issuance of additional units to maintain 2% General Partner interest	26	21	29
Distributions to general partner	(23,698)	(17,691)	(10,244)
Distributions to common unitholders - public	(27,721)	(25,978)	(23,847)
Distributions to common unitholders - Delek Holdings	(46,417)	(42,490)	(25,271)
Distributions to subordinated unitholders - Delek Holdings	0	0	(11,503)
Distributions to Delek Holdings unitholders and general partner related to Big Spring Logistic Assets Acquisition	(98,798)	0	0
Proceeds from revolving credit facility	735,000	277,100	314,750
Payments of revolving credit facility	(458,200)	(489,800)	(273,750)
Proceeds from issuance of senior notes	0	248,112	0
Deferred financing costs paid	(5,264)	(5,951)	0
Reimbursement of capital expenditures by Delek Holdings	5,005	4,262	1,880
Net cash provided by (used in) financing activities	79,933	(52,415)	(27,956)
Net (decrease) increase in cash and cash equivalents	(153)	4,616	59
Cash and cash equivalents at the beginning of the period	4,675	59	0
Cash and cash equivalents at the end of the period	4,522	4,675	59
Cash paid during the period for:
Interest	38,959	19,441	12,206
Income taxes	137	60	224
Non-cash investing activities:
(Increase)/Decrease in accrued capital expenditures	(1,363)	194	480
Non-cash financing activities:
Sponsor contribution of fixed assets	$ 154	$ 67	$ 5,167

General

General	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General Organization As used in this report, the terms "Delek Logistics Partners, LP," the "Partnership," "we," "us," or "our" may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. The Partnership is a Delaware limited partnership formed in April 2012 by Delek US Holdings, Inc. ("Delek Holdings") and its subsidiary Delek Logistics GP, LLC, our general partner (our "general partner'). Effective March 1, 2018 , the Partnership, through its wholly-owned subsidiary DKL Big Spring, LLC, acquired from Delek Holdings certain logistics assets primarily located at or adjacent to Delek Holdings' refinery near Big Spring, Texas (the "Big Spring Refinery") and Delek Holdings' light products distribution terminal located in Stephens County, Oklahoma (collectively, the "Big Spring Logistic Assets" and such transaction the "Big Spring Logistic Assets Acquisition"). See Note 3 for further information regarding the Big Spring Logistic Assets Acquisition. Description of Business The Partnership primarily owns and operates logistics and marketing assets for crude oil and intermediate and refined products. A substantial majority of our existing assets are integral to and dependent on the success of Delek Holdings’ refining and marketing operations. We gather, transport and store crude oil and market, wholesale market, distribute, transport and store refined products in select regions of the southeastern United States and west Texas for Delek Holdings and third parties.

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Accounting Policies	Accounting Policies Basis of Presentation Our consolidated financial statements include the accounts of the Partnership and its subsidiaries. All intercompany accounts and transactions have been eliminated. 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 (“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. In the opinion of management, all adjustments necessary for a fair presentation of the financial condition and the results of operations have been included. All significant intercompany transactions and account balances have been eliminated in consolidation. All adjustments are of a normal, recurring nature. Reclassifications Certain prior period amounts have been reclassified in order to conform to the current year presentation. Additionally, certain changes to presentation of the prior period statements of income have been made in order to conform to the current period presentation, primarily relating to the addition of a subtotal entitled 'cost of sales' which includes all costs directly attributable to the generation of the related revenue, as defined by GAAP, and the retitling of what was previously referred to as 'cost of goods sold' to 'cost of materials and other'. In connection with this change in presentation, we have revised our related accounting policy for ' Cost of Materials and Other and Operating Expenses' presented below. Segment Reporting We are an energy business focused on crude oil, intermediate and refined products pipeline and storage activities and wholesale marketing, terminalling and offloading activities. Management reviews operating results in two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. The pipelines and transportation segment provides crude oil gathering, transportation and storage services to Delek Holdings' refining operations and independent third parties. The wholesale marketing and terminalling segment provides marketing, wholesale marketing and terminalling services to Delek Holdings' 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 revenues less cost of materials and other and operating expenses, excluding depreciation and amortization. Segment reporting is more fully discussed in Note 15 . Cash and Cash Equivalents We maintain cash and cash equivalents in accounts with large, U.S. financial institutions. Any highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents. Accounts Receivable Accounts receivable primarily consists of trade receivables generated in the ordinary course of business. We perform on-going credit evaluations of our customers and generally do not require collateral on accounts receivable. All accounts receivable amounts are considered to be fully collectible. Accordingly, no allowance for doubtful accounts has been established as of December 31, 2018 and 2017 . Two third-party customers accounted for approximately 50.4% of the consolidated accounts receivable balance as of December 31, 2018 . One third-party customer accounted for approximately 22.0% of the consolidated accounts receivable balance as of December 31, 2017 . Inventory Inventory consists of refined products, which are stated at the lower of cost or net realizable value, with cost determined on a first-in, first-out ("FIFO") basis. Delek Holdings accounted for approximately 64.2% of our inventory purchases in our wholesale marketing and terminalling segment during the year ended December 31, 2018 . One third party vendor and Delek Holdings accounted for approximately 65.8% and 11.6% , respectively, of our inventory purchases in our wholesale marketing and terminalling segment during the year ended December 31, 2017 . Two third party vendors in our wholesale marketing and terminalling segment accounted for approximately 72.0% of our inventory purchases during the year ended December 31, 2016 . Property, Plant and Equipment Assets acquired in conjunction with business acquisitions are recorded at estimated fair market value in accordance with the purchase method of accounting as prescribed in Accounting Standards Codification ("ASC") 805, Business Combinations ("ASC 805"). Other acquisitions of property and equipment are carried at cost. Acquisitions of net assets that do not constitute a business are accounted for by allocating the cost of the acquisition to individual assets acquired and liabilities assumed on relative fair value basis and shall not give rise to goodwill as prescribed in ASC 805. 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 Buildings and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 Intangible Assets Intangible assets consist of a long-term supply contract, indefinite-lived rights of way and a long-term marketing agreement. We amortize the definite-lived long-term supply contract on a straight-line basis over the estimated useful life of 11.5 years. The amortization expense pertaining to the long-term supply contract is included in depreciation and amortization in the accompanying consolidated financial statements. The long-term marketing agreement is amortized on a straight-line basis over a 20 year period as a component of net revenues from affiliates. 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. Goodwill is reviewed at least annually for impairment, or more frequently if indicators of impairment exist, such as disruptions in our business, unexpected significant declines in operating results, or a sustained market capitalization decline. Goodwill is evaluated for impairment by comparing the carrying amount of the reporting unit to its estimated fair value. Prior to the adoption of Accounting Standard Update ("ASU") 2017-04, Simplifying the Test for Goodwill Impairment, i f a reporting unit's carrying amount exceeds its fair value (Step 1), the impairment assessment leads to the testing of the implied fair value of the reporting unit's goodwill to its carrying amount (Step 2). If the implied fair value is less than the carrying amount, a goodwill impairment charge is recorded. Subsequent to adoption of ASU 2017-04 (which we adopted during the fourth quarter of 2018, as permitted by the ASU), Step 2 is no longer required, but rather any impairment is determined based on the results of Step 1. In assessing the recoverability of goodwill, assumptions are made with respect to future business conditions and estimated expected future cash flows to determine the fair value of a reporting unit. We may consider inputs such as a market participant weighted average cost of capital, estimated growth rates for revenue, gross profit and capital expenditures based on history and our best estimate of future forecasts, all of which are subject to significant judgment and estimates. We may also estimate the fair values of the reporting units using a multiple of expected future cash flows, such as those used by third-party analysts. If these estimates and assumptions change in the future, due to factors such as a decline in general economic conditions, competitive pressures on sales and margins and other economic and industry factors beyond management's control, an impairment charge may be required. We may also elect to perform a qualitative assessment of goodwill balances. The qualitative assessment permits companies to assess whether it is more likely than not (i.e., a likelihood of greater than 50%) that the fair value of a reporting unit is less than its carrying amount. If a company concludes based on the qualitative assessment that it is more likely than not that the fair value of a reporting unit is less than its carrying amount, the company is required to perform the quantitative impairment test. If a company concludes based on the qualitative assessment that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, it has completed its goodwill impairment test and does not need to perform the quantitative impairment test. Our annual assessment of goodwill did not result in an impairment charge during the years ended December 31, 2018 , 2017 or 2016 . Details of remaining goodwill balances by segment are included in Note 9 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of influence over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Equity investments for which we determine we have significant influence are accounted for as equity method investments. Amounts recognized for equity method investments are included in equity method investments in our consolidated balance sheets and adjusted for our share of the net earnings and losses of the investee and cash distributions, which are separately stated in our consolidated statements of income and comprehensive income and our consolidated statements of cash flows. We evaluate our equity method investments presented for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary. See Note 14 for further information on our equity method investments. Derivatives We record all derivative financial instruments, including forward fuel contracts, at estimated fair value in accordance with the provisions of ASC 815, Derivatives and Hedging ("ASC 815"). Changes in the fair value of the derivative instruments are recognized in operations, unless we elect to apply the hedge accounting treatment permitted under the provisions of ASC 815 allowing such changes to be classified as other comprehensive income for cash flow hedges. We validate the fair value of all derivative financial instruments on a periodic basis, utilizing exchange pricing and/or price index developers, such as Platts or Argus. During the years ended December 31, 2018 , 2017 and 2016 , we did not elect to apply hedge accounting treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of income and comprehensive income. Our policy under the guidance of ASC 815-10-45, Derivatives and Hedging—Other Presentation Matters ("ASC 815-10-45"), is to net the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and offset these values against any cash collateral associated with these derivative positions. See Note 17 for further discussion. Fair Value of Financial Instruments The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments ("ASC 825"). We apply the provisions of ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), in our presentation and disclosures regarding fair value, which pertain to certain financial assets and liabilities measured at fair value in the balance sheet on a recurring basis. ASC 820 defines fair value, establishes a framework for measuring fair value and expands disclosures about such measurements that are permitted or required under other accounting pronouncements. See Note 16 for further discussion. We apply the provisions of ASC 825 as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. By electing the fair value option in conjunction with a derivative, an entity can achieve an accounting result similar to a fair value hedge without having to comply with complex hedge accounting rules. As of December 31, 2018 and 2017 , 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 Holdings employees providing services to the Partnership are covered under Delek Holdings’ insurance programs. Delek Holdings has workers' compensation and liability insurance with varying retentions and deductibles with limits that management considers adequate. Environmental Expenditures We have historically accrued environmental and clean-up related costs of a non-capital nature when it is both probable that a liability has been incurred and the amount can be reasonably estimated. Environmental liabilities represent the current estimated costs to investigate and remediate contamination at our properties. This estimate is based on internal and third-party assessments of the extent of the contamination, the selected remediation technology and review of applicable environmental regulations, typically considering estimated activities and costs for the next 15 years, unless a specific longer range estimate is practicable. Accruals for estimated costs from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study and include, but are not limited to, costs to perform remedial actions and costs of machinery and equipment that are dedicated to the remedial actions and that does not have an alternative use. Such accruals are adjusted as further information develops or circumstances change. We discount environmental liabilities to their present value if payments are fixed and determinable. Expenditures for equipment necessary for environmental issues relating to ongoing operations are capitalized. Estimated recoveries of costs from other parties are recorded on an undiscounted basis as assets when their realization is deemed probable. See Note 19 for further information on crude oil releases impacting our properties and related accruals. 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, 2018 and 2017 is as follows (in thousands): December 31, 2018 2017 Beginning balance $ 4,064 $ 3,772 Liabilities acquired 768 — Accretion expense 359 292 Ending balance $ 5,191 $ 4,064 In order to determine fair value, management must make certain estimates and assumptions including, among other things, projected cash flows, a credit-adjusted risk-free rate and an assessment of market conditions that could significantly impact the estimated fair value of the asset retirement obligation. Revenue Recognition Revenue is measured based on consideration specified in a contract with a customer. The Partnership recognizes revenue when it satisfies a performance obligation by transferring control over a product or by providing services to a customer. The adoption of ASC 606, Revenue from Contracts with Customers ("ASC 606"), did not materially change our revenue recognition patterns, which are described below. The principles for recognizing revenue as codified in ASC 605, Revenue Recognition ("ASC 605"), were applied during the years ended December 31, 2017 and 2016 . No restatements to revenues or expenses were required to be made to our consolidated statements of income, as we applied the modified retrospective transition method in adopting ASC 606, as described below under "—New Accounting Pronouncements Adopted During 2018— ASU 2014-09, Revenue - Revenue from Contracts with Customers ." Revenues for products sold are generally recognized upon delivery of product, which is when title and control of the product is transferred. Transaction prices for these products are typically at market rates for the product at the time of delivery. Service revenues are recognized as crude oil, intermediate and refined products are shipped through, delivered by or stored in our pipelines, trucks, terminals and storage facility assets, as applicable. We do not recognize product revenues for these services, as the product does not represent a promised good in the context of ASC 606. All service revenues are based on regulated tariff rates or contractual rates. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. Certain agreements for gathering, transportation, storage, terminalling, and offloading with Delek Holdings are considered operating leases under ASC 840, Leases ("ASC 840"). We identified the separate lease and service components of our revenues under these leases and applied ASC 606 only to the service component, while the lease component continued to be accounted for under ASC 840. Refer to Note 5 for further information. Cost of Materials and Other and Operating Expenses Cost of materials and other includes (i) all costs of purchased refined products, additives and related transportation of such products, (ii) costs associated with the operation of our trucking assets, which primarily include allocated employee costs and other costs related to fuel, truck leases and repairs and maintenance, (iii) the cost of pipeline capacity leased from a third-party, and (iv) gains and losses related to our commodity hedging activities. Operating expenses include the costs associated with the operation of owned terminals and pipelines and terminalling expense at third-party locations, excluding depreciation and amortization. These costs primarily include outside services, allocated employee costs, repairs and maintenance costs and energy and utility costs. Operating expenses related to the wholesale business are excluded from cost of sales because they primarily relate to costs associated with selling the products through our wholesale business. Depreciation and amortization is separately presented in our statement of income and disclosed by reportable segment in Note 15 . Deferred Financing Costs Deferred financing costs are included in other non-current assets in the accompanying consolidated balance sheets and represent expenses related to issuing and amending our revolving credit facility. Deferred financing costs associated with our 6.750% Senior Notes are included as a reduction to the associated debt balance in the accompanying consolidated balance sheets. These costs represent expenses related to issuing the senior notes. These amounts are amortized ratably over the remaining term of the respective financing and are included in interest expense in the accompanying consolidated statements of income and comprehensive income. Operating Leases We lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term, to renew the leases. None of these lease arrangements include fixed rental rate increases. Income Taxes We are not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of these income taxes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under the First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement"). We are subject to income taxes in certain states that do not follow the federal tax treatment of Partnerships. These taxes are accounted for under the provisions of ASC 740, Income Taxes ("ASC 740"). This statement generally requires the Partnership 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. 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. The fair value of our phantom units is determined based on the closing market 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 one- to five-year service periods, unless such awards are amended in accordance with the LTIP (as defined in Note 13 ). It is our practice to issue new units when phantom units vest. Net Income per Limited Partner Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and incentive distribution rights ("IDRs"). The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs, by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our Partnership Agreement. The weighted-average number of common units reflects the conversion of the subordinated units to common units on February 25, 2016. See Notes 6 and 12 for further discussion. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. As of December 31, 2018 , the only potentially dilutive units outstanding consist of unvested phantom units. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding. Comprehensive Income Comprehensive income for the years ended December 31, 2018 , 2017 and 2016 was equivalent to net income. Up-front Payments to Customers We record all up-front payments to customers in accordance with the provisions of ASC 606. We evaluate the nature of each payment, the rights and obligations under the related contract, and whether the payment meets the definition of an asset. When an asset is recognized for an up-front payment to a customer, the asset is amortized, as a reduction of revenue, in a manner that reflects the pattern and period over which the asset is expected to provide benefit. Sales, Use and Excise Taxes Prior to the adoption of ASC 606, the Partnership's policy was to exclude sales, use and excise taxes from revenue when we are an agent of the taxing authority, in accordance with the applicable guidance in ASC 605. Upon the adoption of ASC 606, we made the accounting policy election to exclude from revenue all taxes assessed by a governmental authority, including sales, use and excise taxes, that are both imposed on and concurrent with a specific revenue-producing transaction and collected on behalf of a customer. New Accounting Pronouncements Adopted During 2018 ASU 2017-09, Stock Compensation - Scope of Modification Accounting In May 2017, the FASB issued guidance that clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as modifications. The modification accounting guidance applies if the value, vesting conditions or classification of the award changes. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. This guidance should be applied prospectively to an award modified on or after the adoption date. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations. ASU 2017-05, Other Income - Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets In February 2017, the FASB issued guidance clarifying the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The amendments in this guidance should be applied using either i) a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption or ii) a retrospective basis to each period presented in the financial statements. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We adopted this guidance on January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations. ASU 2017-04, Intangible - Simplifying the Test for Goodwill Impairment In January 2017, the FASB issued guidance concerning the goodwill impairment test that eliminates Step 2, which required a comparison of the implied fair value of goodwill of the reporting unit with the carrying amount of that goodwill for that reporting unit. It also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative assessment, to perform Step 2 of the goodwill impairment test. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. This guidance is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. As permitted under Accounting Standards Update 2017-04, we adopted this guidance in the fourth quarter of 2018 in connection with our 2018 goodwill impairment tests. The adoption did not have a material impact on our business, financial condition or results of operations. ASU 2016-15, Statement of Cash Flow - Classification of Certain Cash Receipts and Cash Payments In August 2016, the FASB issued guidance that clarifies eight cash flow classification issues pertaining to cash receipts and cash payments. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations, except for reclassifications of certain distributions received from equity method investees, due to us making an accounting policy election to classify distributions received from equity method investees using the cumulative earnings approach. Under this approach, distributions received are considered returns on investment and classified as cash inflows from operating activities, unless the investor’s cumulative distributions received less distributions received in prior periods that were determined to be returns of investment exceed cumulative equity in earnings (as adjusted for amortization of basis differences) recognized by the investor. When such an excess occurs, the current-period distribution up to this excess should be considered a return of investment and classified as cash inflows from investing activities. This resulted in a reclassification of $0.8 million of distributions received in the year ended December 31, 2017 from the line item entitled dividends from equity method investments in net cash provided by (used in) operating activities to the line item entitled distributions from equity method investments in net cash provided by (used in) investing activities in the consolidated statements of cash flows. ASU 2016-07, Investment - Simplifying the Transition to the Equity Method of Accounting In January 2016, the FASB issued guidance that affects the accounting for equity investments, financial liabilities accounted for under the fair value option and the presentation and disclosure requirements for financial instruments. Under the new guidance, all equity investments in un

Acquisitions Acquisitions

Acquisitions Acquisitions	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Acquisitions	Acquisitions Big Spring Logistic Assets Acquisition Effective March 1, 2018 , the Partnership, through its wholly-owned subsidiary DKL Big Spring, LLC, acquired the Big Spring Logistic Assets from Delek Holdings, which are primarily located at or adjacent to the Big Spring Refinery. The total purchase price was $170.8 million , financed through borrowings under the Partnership’s revolving credit facility. The Big Spring Logistic Assets include: • Approximately 75 storage tanks and certain ancillary assets (such as tank pumps and piping) primarily located adjacent to the Big Spring Refinery; • An asphalt terminal and a light products terminal; • Certain crude oil and refined product pipelines; and • Other logistics assets, such as four underground saltwells used for natural gas liquids storage. In connection with the closing of the transaction, Delek Holdings, the Partnership and various of their respective subsidiaries entered into and amended certain existing contracts, including entering into new pipelines, storage and throughput facilities and asphalt services agreements. The transaction and related agreements were approved by the Conflicts Committee of the Partnership's general partner, which is comprised solely of independent directors. See Note 4 for more detailed descriptions of these agreements. The Big Spring Logistic Assets Acquisition was considered a transaction between entities under common control. Accordingly, the Big Spring Logistic Assets were recorded at amounts based on Delek Holdings' historical carrying value as of the acquisition date. The excess of the cash paid over the historical carrying value of the assets acquired from Delek Holdings amounted to $98.8 million and was recorded as a reduction in equity. The historical carrying value of the Big Spring Logistic Assets as of the acquisition date was $72.0 million , which is net of $0.8 million of assumed asset retirement obligations. Prior periods have not been recast, as these assets did not constitute a business in accordance with Accounting Standard Update 2017-01, "Clarifying the Definition of a Business." We capitalized approximately $0.4 million of acquisition costs related to the Big Spring Logistic Assets Acquisition during the year ended December 31, 2018 . Marketing Contract Intangible Acquisition Additionally, concurrent with the Big Spring Logistic Assets Acquisition, Delek Holdings, the Partnership and various of their respective subsidiaries entered into a new marketing agreement, whereby the Partnership markets certain refined products produced at or sold from the Big Spring Refinery to various customers in return for a marketing fee (the "Marketing Contract Intangible Acquisition"). We recorded a related contract intangible asset in the amount of $144.2 million based on the amount paid to enter into the contract, which represents the fair value of the intangible asset. The contract intangible asset is amortized over a twenty year period as a component of net revenues from affiliates. The total consideration paid was financed through borrowings under the Partnership's revolving credit facility. This transaction and related marketing agreement were approved by the Conflicts Committee of the Partnership's general partner, which is comprised solely of independent directors. See Note 4 for a more detailed description of this marketing agreement. Big Spring Acquisition On September 15, 2017 , the Partnership, through its wholly owned subsidiary, Delek Marketing & Supply, LP acquired from Plains Pipeline, L.P. an approximate 40 -mile pipeline and related ancillary assets (the "Big Spring Pipeline") (such transaction, the "Big Spring Acquisition") for approximately $9.0 million to complement our existing asset base. The Big Spring Pipeline originates in Big Spring, Texas and terminates in Midland, Texas. The Big Spring Acquisition was accounted for as an asset acquisition. The allocation of the relative fair value assigned to property, plant and equipment and intangible assets amounted to $6.4 million and $2.6 million

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Commercial Agreements The Partnership has a number of long-term, fee-based commercial agreements with Delek Holdings under which we provide various services, including crude oil gathering and crude oil, intermediate and refined products transportation and storage services, and marketing, terminalling and offloading services to Delek Holdings. Most of these agreements have an initial term ranging from five to ten years, which may be extended for various renewal terms at the option of Delek Holdings. In November 2017, Delek Holdings opted to renew certain of these agreements for subsequent five-year terms expiring in November 2022. In the case of our marketing agreement with Delek Holdings in respect to the Tyler Refinery, the initial term has been extended through 2026. The current term of certain of our agreements with Delek Holdings were required to be further extended pursuant to the amended and restated DKL Credit Facility (as defined in Note 11 ), which extensions were effective in the fourth quarter of 2018. The fees under each agreement are payable to us monthly by Delek Holdings or certain third parties to whom Delek Holdings has assigned certain of its rights and are generally subject to increase or decrease on July 1 of each year, by the amount of any change in various inflation-based indices, including the Federal Energy Regulatory Commission ("FERC") oil pipeline index or various iterations of the consumer price index ("CPI") and the producer price index ("PPI"); provided, however, that in no event will the fees be adjusted below the amount initially set forth in the applicable agreement. In most circumstances, if Delek Holdings or the applicable third party assignee fails to meet or exceed the minimum volume or throughput commitment during any calendar quarter, Delek Holdings, 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, subject to certain exceptions as specified in the applicable agreement. Carry-over of any volumes or revenue in excess of such commitment to any subsequent quarter is not permitted. Under each of these agreements, we are required to maintain the capabilities of our pipelines and terminals, such that Delek Holdings may throughput and/or store, as the case may be, specified volumes of crude oil, intermediate and refined products. To the extent that Delek Holdings is prevented by our failure to maintain such capacities from throughputting or storing such specified volumes for more than 30 days per year, Delek Holdings' 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. Our material commercial agreements with Delek Holdings 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 (2) : Crude Oil Pipelines (non-gathered) November 2012 5 / 15 Crude oil and refined products transportation 46,000 (3) $0.99 (4) Refined Products Pipelines November 2012 5 / 15 40,000 $0.12 SALA Gathering System November 2012 5 / 15 Crude oil gathering 14,000 $2.66 (4) East Texas Crude Logistics System (2) : Crude Oil Pipelines November 2012 5 / 15 Crude oil transportation and storage 35,000 $0.47 (5) Storage November 2012 5 / 15 N/A $291,220/month East Texas Marketing November 2012 10 (6) Marketing products for Tyler Refinery 50,000 $0.80 (6) Big Sandy Terminal: (2) (7) Refined Products Transportation November 2012 5 / 15 Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery 5,000 $0.58 Terminalling November 2012 5 / 15 5,000 $0.58 Storage November 2012 5 / 15 N/A $58,192/month Tyler Throughput and Tankage (2) : Refined Products Throughput July 2013 8/ 16 Dedicated Terminalling and storage 50,000 $0.37 Storage July 2013 8/ 16 N/A $871,336/month Memphis Pipeline October 2013 5 Refined Products Transportation 10,959 $1.41 El Dorado Throughput and Tankage (2) : Refined Products Throughput February 2014 8/ 16 Dedicated terminalling and storage 11,000 $0.53 Storage February 2014 8/ 16 N/A $1,363,985/month El Dorado Assets Throughput: Light Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (8) $1.05 Heavy Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (8) $2.36 Pipelines, Storage and Throughput Facilities Agreement (Big Spring): Crude Oil and Refined Products Throughput March 1, 2018 10/15 Pipeline throughput 104,300 0.05 Rail Offloading March 1, 2018 10/15 Offloading services 4,500 0.4 Terminalling March 1, 2018 10/15 Dedicated Terminalling 29,250 0.66 Storage March 1, 2018 10/15 Storage NA $1,374,630/month Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (/bbl) Asphalt Services Agreement (Big Spring): Terminalling March 1, 2018 10/15 Dedicated Asphalt Terminalling and Storage 1,020 to 2,380 based on seasonality 8.3 Storage March 1, 2018 10/15 N/A $456,490/month Marketing Agreement (Big Spring): Marketing Services March 1, 2018 10/15 Dedicated Marketing and Selling 65,000 $0.50 - $0.71 (1) Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof. (2) The current term of the agreement was extended through March 31, 2024 in connection with the amendment and restatement of the DKL Credit Facility (as defined in Note 11 ). While the current terms of the agreement were extended, the upcoming renewal terms were reduced. Therefore, the overall duration of the maximum term above remains unchanged. (3) Excludes volumes gathered on the SALA Gathering System. (4) 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. (5) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.700 /bbl. (6) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.750 /bbl. Following the primary term, the marketing agreement automatically renews for successive one-year term, unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. The initial primary term for the marketing agreement has been extended through 2027. (7) On July 19, 2013, we acquired the Hopewell Pipeline in order to effectively connect it with the Big Sandy Pipeline and thereby return the Big Sandy Terminal to operation. In connection with the acquisition, on July 25, 2013, we and Delek Holdings 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 November 2012. (8) The throughput agreement provides for a minimum throughput fee of $1.5 million per quarter for throughput of a combination of light and heavy crude. Pursuant to an arrangement with Delek Holdings and Lion Oil Company ("Lion Oil"), to which we are not a party, J. Aron & Company ("J. Aron") acquires and holds title to substantially all crude oil, intermediate and refined products transported on our Lion Pipeline System, SALA Gathering System and on pipeline capacity we lease from Enterprise TE Products Pipeline Company LLC that runs from the El Dorado Refinery to our Memphis Terminal (the "Memphis Pipeline"). J. Aron is therefore considered the shipper for the liquid it owns on the Lion Pipeline System, the SALA Gathering System and the Memphis Pipeline. J. Aron also has title to the refined products stored at our Memphis, North Little Rock and El Dorado terminals and in the El Dorado storage tanks. Under (i) our pipelines and storage agreement with Lion Oil relating to the Lion Pipeline System and the SALA Gathering System, (ii) our terminalling agreements with Lion Oil relating to the Memphis and North Little Rock terminals and (iii) our throughput and tankage agreement relating to the terminal and tank assets at and adjacent to the El Dorado Refinery, 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 terminal and tank assets at and adjacent to the El Dorado Refinery, with Lion Oil acting as J. Aron's agent for scheduling purposes. Pursuant to a similar arrangement with Delek Holdings and Alon USA, LP, hereinafter referred to as "Big Spring Refining," J. Aron acquires and holds either title to or a lien on a portion of the crude oil, intermediate and refined products shipped on pipelines or stored at the terminal and storage tanks acquired in the Big Spring Logistic Assets Acquisition. Under (i) our pipelines, storage and throughput facilities agreement with Big Spring Refining relating to certain storage tanks, pipelines and a terminal in Duncan, Oklahoma and (ii) our asphalt services agreement with Big Spring Refining relating to asphalt storage and terminalling near the Big Spring Refinery, Big Spring Refining 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 storage and terminalling assets at or adjacent to the Big Spring Refinery, with Big Spring Refining acting as J. Aron's agent for scheduling purposes. Accordingly, even though this is effectively a financing arrangement for Delek Holdings and its subsidiaries whereby J. Aron sells the product back to Delek Holdings and its subsidiaries, J. Aron is technically our primary customer under each of these agreements. J. Aron retains these storage and transportation rights for the term of its arrangement with Lion Oil, which currently runs through April 30, 2020, and for the term of its arrangement with Big Spring Refining, which currently runs through May 31, 2021, unless terminated earlier pursuant to the terms of the arrangement. J. Aron pays us for the transportation, throughput and storage services we provide to it. The rights assigned to J. Aron do not alter the obligations of Lion Oil or Big Spring Refining to meet certain throughput minimum volumes under our agreements with respect to the transportation, throughputting and storage of crude oil, intermediate and refined products through our facilities, but J. Aron's throughput is credited toward minimum throughput commitments of Lion Oil and Big Spring. Accordingly, Lion Oil and Big Spring are 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. Big Spring Pipeline, Storage and Throughput Facilities Agreement In connection with the Big Spring Logistic Assets Acquisition, Alon USA, LP, a Texas limited partnership and an indirect, wholly-owned subsidiary of Delek Holdings (“Alon USA, LP”), and DKL Big Spring, LLC, a Delaware limited liability company and a wholly-owned subsidiary of the Partnership, entered into the Pipelines, Storage and Throughput Facilities Agreement (Big Spring Refinery Logistic Assets and Duncan Terminal) (the “Logistics Agreement”). Under the Logistics Agreement, the Partnership will provide storage and throughput services at certain of the Big Spring Logistic Assets for Alon USA, LP. The Partnership will act as bailee of crude oil and refined petroleum products owned by Alon USA, LP or its assignee held in such assets owned and operated by the Partnership. The Partnership will charge fees to Alon USA, LP based on throughput volumes received or delivered ranging from $0.05 to $0.66 per barrel and related storage fees depending on the type of service or product. The fees under the Logistics Agreement may be adjusted annually for inflation. The initial term of the Logistics Agreement is ten years ; the Partnership has a one-time option to extend the Logistics Agreement for up to five additional years; and the Logistics Agreement will continue on a year-to-year basis following such renewal term unless terminated by either party. Big Spring Asphalt Services Agreement In connection with the Big Spring Logistic Assets Acquisition, Alon USA, LP and the Partnership entered into the Big Spring Asphalt Services Agreement (the “Asphalt Services Agreement”). Under the Asphalt Services Agreement, the Partnership will provide asphalt storage and handling services at certain of the Big Spring Logistic Assets (such assets, the “Asphalt Facilities”). The Partnership will provide services to Alon USA, LP at the Asphalt Facilities and serve as bailee of all raw materials, and other hydrocarbons, used to make asphalt products owned by Alon USA, LP or its assignee held in the Asphalt Facilities. The Partnership will charge fees to Alon USA, LP based on throughput volumes delivered of $8.30 per barrel and related storage fees. The fees under the Asphalt Services Agreement may be adjusted annually for inflation. The initial term of the Asphalt Services Agreement is ten years ; the Partnership has a one-time option to extend the Asphalt Services Agreement for up to five additional years; and the Asphalt Services Agreement will continue on a year-to-year basis following such renewal term unless terminated by either party. Big Spring Marketing Agreement Concurrent with the Big Spring Logistic Assets Acquisition, Alon USA, LP and the Partnership entered into the Marketing Agreement (the “Marketing Agreement”). Under the Marketing Agreement, the Partnership will provide Alon USA, LP with services for the marketing and selling of certain refined petroleum products that are produced or sold from the Big Spring Refinery. The Partnership will charge Alon USA, LP fees for such marketing and selling services of $0.50 to $0.71 per barrel depending on the type of product. The fees under the Marketing Agreement may be adjusted annually for inflation. The initial term of the Marketing Agreement is ten years ; Alon USA, LP has a one-time option to extend the Marketing Agreement for up to five additional years; and the Marketing Agreement will continue on a year-to-year basis following such renewal term unless terminated by either party. Other Agreements with Delek Holdings In addition to the commercial agreements described above, the Partnership has entered into the following agreements with Delek Holdings: Omnibus Agreement The Partnership entered into an omnibus agreement with Delek Holdings, our general partner, Delek Logistics Operating, LLC, Lion Oil Company and certain of the Partnership’s and Delek Holdings' other subsidiaries on November 7, 2012, which was subsequently amended and restated on July 26, 2013, February 10, 2014, March 31, 2015 and August 3, 2015 and was further amended effective March 1, 2018 in connection with the Big Spring Logistic Assets Acquisition (collectively, as amended, the "Omnibus Agreement"). The Omnibus Agreement governs the provision of certain operational services and reimbursement obligations, among other matters, between the Partnership and Delek Holdings. In conjunction with the March 1, 2018 amendment, our obligation to pay an annual fee to Delek Holdings for its provision of centralized corporate services to the Partnership was increased to $3.9 million . Pursuant to the terms of the Omnibus Agreement, we were reimbursed by Delek Holdings for certain capital expenditures in the amount of $5.0 million , $4.3 million and $1.9 million , during the years ended December 31, 2018 , 2017 and 2016 , respectively. These amounts are recorded in other long-term liabilities and are amortized to revenue over the life of the underlying revenue agreement corresponding to the asset. Additionally, we are reimbursed or indemnified, as the case may be, for costs incurred in excess of certain amounts related to certain asset failures, pursuant to the terms of the Omnibus Agreement. As of December 31, 2018 , we have recorded a receivable from related parties of $1.6 million for these matters for which we expect to be reimbursed, which reimbursements are recorded as reductions to operating expense. We were reimbursed $8.2 million , $0.3 million and $1.2 million for these matters during the year ended December 31, 2018 2017 and 2016 , respectively. Other Agreements 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, which include certain labor related costs. We and our subsidiaries paid Delek Holdings approximately $21.1 million , $18.8 million and $15.7 million pursuant to the Partnership Agreement during the years ended December 31, 2018 , 2017 and 2016 , respectively. These amounts are included in operating expenses in the accompanying consolidated statements of income and comprehensive income. Other Transactions The Partnership is currently managing a long-term capital project on behalf of Delek Holdings pursuant to a construction management and operating services agreement (the "DPG Management Agreement") for the construction of a 250-mile gathering system in the Permian Basin (the "Delek Permian Gathering Project"). The Partnership is also considered the operator for the project and will oversee functions such as oversight of project design, procurement and construction of project segments and provide other related services. Pursuant to the terms of the DPG Management Agreement, the Partnership receives a monthly operating services fee and a construction services fee, which includes the Partnership's direct costs of managing the project plus an additional percentage fee of the construction costs of each project segment. The agreement extends through December 2022. Total fees paid to the Partnership for the year ended December 31, 2018 were $4.8 million . Additionally, the Partnership incurs the costs in connection with the construction of the assets and is subsequently reimbursed by Delek Holdings. Amounts reimbursable by Delek Holdings are recorded in accounts receivable from related parties. Summary of Transactions Revenues from affiliates consist primarily of revenues from gathering, transportation, storage, offloading, Renewable Identification Numbers, wholesale marketing and products terminalling services provided primarily to Delek Holdings based on regulated tariff rates or contractually based fees and product sales. Affiliate operating expenses are primarily comprised of amounts we reimburse Delek Holdings, or our general partner, as the case may be, for the services provided to us under the Partnership Agreement. These expenses could also include reimbursement and indemnification amounts from Delek Holdings, as provided under the Omnibus Agreement. Additionally, the Partnership is required to reimburse Delek Holdings for direct or allocated costs and expenses incurred by Delek Holdings on behalf of the Partnership and for charges Delek Holdings incurred for the management and operation of our logistics assets, including an annual fee for various centralized corporate services, which are included in general and administrative services. In addition to these transactions, we purchase refined products and bulk biofuels from Delek Holdings, the costs of which are included in cost of materials and other. A summary of revenue, purchases from affiliates and expense transactions with Delek Holdings and its affiliates are as follows (in thousands): Year Ended December 31, 2018 2017 2016 Revenues $ 240,809 $ 156,280 $ 149,564 Purchases from Affiliates $ 349,089 $ 54,982 $ 32,514 Operating and maintenance expenses $ 36,182 $ 29,483 $ 27,668 General and administrative expenses $ 8,250 $ 7,492 $ 6,254 Quarterly Cash Distribution Our common and general partner unitholders and the holders of IDRs are entitled to receive quarterly distributions of available cash as it is determined by the board of directors of our general partner in accordance with the terms and provisions of our Partnership Agreement. During the years ended December 31, 2018 , 2017 and 2016 , we paid quarterly cash distributions of $101.9 million , $87.9 million and $75.0 million , respectively, of which $70.1 million , $60.1 million and $47.0 million , respectively, were paid to Delek Holdings and our general partner. On January 24, 2019 , our general partner's board of directors declared a quarterly cash distribution totaling $26.9 million based on the available cash as of the date of determination for the end of the fourth quarter of 2018 , which was paid on February 12, 2019 to unitholders of record on February 4, 2019 . The distribution included $19.6 million

Revenues

Revenues	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenues	Revenues We generate revenue by charging fees for gathering, transporting, offloading and storing crude oil; for storing intermediate products and feed stocks; for distributing, transporting and storing refined products; for marketing refined products output of Delek Holdings' Tyler and Big Spring refineries; and for wholesale marketing in the west Texas area. A significant portion of our revenue is derived from long-term commercial agreements with Delek Holdings, which provide for annual fee adjustments for increases or decreases in the CPI, PPI or FERC index (refer to Note 4 for a more detailed description of these agreements). In addition to the services we provide to Delek Holdings, we also generate substantial revenue from crude oil, intermediate and refined products transportation services for, and terminalling and marketing services to, third parties primarily in Texas, New Mexico, Tennessee and Arkansas. Certain of these services are provided pursuant to contractual agreements with third parties. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. Delek Holdings, directly or indirectly, accounted for 36.6% , 28.9% and 32.8% of our total revenues for the years ended December 31, 2018 , 2017 and 2016 , respectively. Sunoco LP accounted for 15.9% , 9.0% and 10.5% of our total revenues for the years ended December 31, 2018 , 2017 and 2016 , respectively. The majority of our commercial agreements with Delek Holdings meet the definition of a lease since: (1) performance of the contracts is dependent on specified property, plant or equipment and (2) it is remote that one or more parties other than Delek Holdings will take more than a minor amount of the output associated with the specified property, plant or equipment. As part of our adoption of ASC 606, we applied the new revenue recognition standard only to the service component of these leases. The bifurcation of the lease and service components was based on an analysis of lease-related and service-related costs for each contract, adjusted for representative profit margins. The lease component continues to be accounted for under the applicable lease accounting guidance. The following table represents a disaggregation of revenue for each reportable segment for the periods indicated (in thousands): Year Ended December 31, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 15,149 $ 870 $ 16,019 Service Revenue - Affiliate (1) 93,300 53,750 147,050 Product Revenue - Third Party — 400,781 400,781 Product Revenue - Affiliate — 35,252 35,252 Lease Revenue - Affiliate 45,118 13,389 58,507 Total Revenue $ 153,567 $ 504,042 $ 657,609 (1) Net of $6.0 million of amortization expense for the year ended, related to a customer contract intangible asset recorded in the wholesale marketing and terminalling segment. As of December 31, 2018 , we expect to recognize approximately $1.1 billion in service and lease revenues related to our unfulfilled performance obligations pertaining to the minimum volume commitments and capacity utilization under the non-cancelable terms of our commercial agreements with Delek Holdings. We do not disclose information about remaining performance obligations that have original expected durations of one year or less. Our unfulfilled performance obligations as of December 31, 2018 were as follows (in thousands): 2019 168,315 2020 167,965 2021 167,620 2022 166,587 2023 and thereafter 474,200 Total expected revenue on remaining performance obligations $ 1,144,687

Net Income Per Unit

Net Income Per Unit	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Net Income Per Unit	Net Income Per Unit We use the two-class method when calculating the net income per unit applicable to limited partners, because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and IDRs. The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2.0% interest and IDRs, by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs, which are held by our general partner pursuant to our Partnership Agreement. The IDRs are paid following the close of each quarter. Earnings in excess of distributions are allocated to our general partner and limited partners based on their respective ownership interests. Payments made to our unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of net income per unit. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. As of December 31, 2018 , 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. Following the February 12, 2016 payment of the cash distribution attributable to the fourth quarter of 2015 and confirmation by the board of directors of our general partner (based on the recommendation of the Conflicts Committee) on February 25, 2016 that the requirements under the Partnership Agreement for the conversion of all subordinated units into common units were satisfied, the subordination period ended. As a result, in the first quarter of 2016, all of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. The conversion did not impact the amount of the cash distribution paid or the total number of the Partnership's outstanding units representing limited partner interests. The Partnership's net income was allocated to the general partner and the limited partners, including the holders of the subordinated units through February 24, 2016, in accordance with our Partnership Agreement. Our distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below represents total cash distributions applicable to the period in which the distributions are earned. The date of distribution for the distributions earned during the period ended December 31, 2018 is February 12, 2019 . The calculation of net income per unit is as follows (dollars in thousands, except per unit amounts): Year Ended December 31, 2018 2017 2016 Net income attributable to partners $ 90,182 $ 69,409 $ 62,804 Less: General partner's distribution (including IDRs) (1) 25,777 18,797 12,437 Less: Limited partners' distribution 76,113 69,057 58,158 Less: Subordinated partner's distribution — — 4,424 Distributions in excess of earnings $ (11,708 ) $ (18,445 ) $ (12,215 ) General partner's earnings: Distributions (including IDRs) (1) $ 25,777 $ 18,797 $ 12,437 Allocation of distributions in excess of earnings (234 ) (368 ) (244 ) Total general partner's earnings $ 25,543 $ 18,429 $ 12,193 Limited partners' earnings on common units: Distributions $ 76,113 $ 69,057 $ 58,158 Allocation of distributions in excess of earnings (11,474 ) (18,077 ) (11,489 ) Total limited partners' earnings on common units $ 64,639 $ 50,980 $ 46,669 Limited partners' earnings on subordinated units: Distributions $ — $ — $ 4,424 Allocation of (distributions) earnings excess — — (482 ) Total limited partner's earnings on subordinated units $ — $ — $ 3,942 Weighted average limited partner units outstanding (2) : Common units - (basic) 24,390,286 24,348,063 22,490,264 Common units - (diluted) 24,396,881 24,376,972 22,558,717 Subordinated units - Delek Holdings (basic and diluted) (3) — — 1,803,167 Net income per limited partner unit (2) : Common - (basic) $ 2.65 $ 2.09 $ 2.08 Common - (diluted) (4) $ 2.65 $ 2.09 $ 2.07 Subordinated - (basic and diluted) $ — $ — $ 2.19 (1) General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs. (2) We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflects the conversion of the subordinated units to common units on February 25, 2016. (3) On February 25, 2016, all of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. Distributions and the Partnership's net income were allocated to the subordinated units through February 24, 2016. (4) Outstanding common unit equivalents totaling 1,776 and 4,240 were excluded from the diluted earnings per unit calculation for the years ended December 31, 2018 and 2016 , respectively, as these common unit equivalents did not have a dilutive effect under the treasury stock method. There were no outstanding common unit equivalents excluded from the diluted earnings per unit calculation during the year ended December 31, 2017

Inventory

Inventory	12 Months Ended
	Dec. 31, 2018
Inventory, Net [Abstract]
Inventory	Inventory Inventories consisted of $5.5 million and $20.9 million of refined petroleum products as of December 31, 2018 and 2017 , respectively. Inventory is stated at the lower of cost or net realizable value, with cost determined on a FIFO basis. We recognize lower of cost or net realizable value charges as a component of cost of materials and other in the consolidated statements of income and comprehensive income, which amounted to $0.2 million and a nominal amount during the years ended December 31, 2018 and 2017 , respectively. There was no lower of cost or net realizable value charge during the year ended December 31, 2016

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment, at cost, consist of the following (in thousands): December 31, 2018 2017 Land $ 4,458 $ 4,440 Building and building improvements 3,695 2,804 Pipelines, tanks and terminals 410,154 314,251 Asset retirement obligation assets 2,073 2,073 Other equipment 15,838 14,650 Construction in process 16,528 28,961 452,746 367,179 Less: accumulated depreciation (140,184 ) (112,111 ) $ 312,562 $ 255,068 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2018 and 2017 are as follows (in thousands): As of and For the Year Ended December 31, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 361,702 $ 91,044 $ 452,746 Less: accumulated depreciation (106,971 ) (33,213 ) (140,184 ) Property, plant and equipment, net $ 254,731 $ 57,831 $ 312,562 Depreciation expense $ 21,115 $ 4,786 $ 25,901 As of and For the Year Ended December 31, 2017 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 300,134 $ 67,045 $ 367,179 Less: Accumulated depreciation (84,435 ) (27,676 ) (112,111 ) Property, plant and equipment, net $ 215,699 $ 39,369 $ 255,068 Depreciation expense $ 17,268 $ 3,583 $ 20,851

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2018
Goodwill [Abstract]
Goodwill	Goodwill Goodwill represents the excess of the aggregate purchase price over the fair value of the identifiable net assets acquired and is not amortized. Our goodwill relates to the west Texas assets contributed to us by Delek Marketing & Supply, LLC ("Delek Marketing"), a direct wholly owned subsidiary of Delek Holdings, in connection with our initial public offering (the "Offering") and to the purchase price allocation of certain of our third party acquisitions. We perform an annual assessment of whether goodwill retains its value. This assessment is done more frequently if indicators of potential impairment exist. We performed our annual goodwill impairment review in the fourth quarter of 2018 , 2017 and 2016 . We performed a qualitative assessment for the year ended December 31, 2018 . During the years ended December 31, 2017 and 2016 , 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 2018 , 2017 and 2016 , the annual impairment review resulted in the determination that no impairment of goodwill had occurred. Our goodwill accounts in our wholesale marketing and terminalling segment amounted to $7.5 million as of December 31, 2018 , 2017 and 2016 . Our goodwill accounts in our pipelines and transportation segment amounted to $4.7 million as of December 31, 2018 , 2017 and 2016

Other Intangible Assets

Other Intangible Assets	12 Months Ended
	Dec. 31, 2018
Other Intangible Assets Disclosure [Abstract]
Other Intangible Assets	Other Intangible Assets Our identifiable intangible assets are as follows (in thousands): Useful Accumulated As of December 31, 2018 Life Gross Amortization Net Intangible assets subject to amortization: Supply contract 11.5 $ 12,227 $ (12,227 ) $ — Marketing contract 20 $ 144,219 $ (6,009 ) 138,210 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 15,828 15,828 Total $ 172,274 $ (18,236 ) $ 154,038 Useful Accumulated As of December 31, 2017 Life Gross Amortization Net Intangible assets subject to amortization: Supply contract 11.5 $ 12,227 $ (12,138 ) $ 89 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 15,828 15,828 Total $ 28,055 $ (12,138 ) $ 15,917 Amortization of intangible assets was $6.1 million during the year ended December 31, 2018 and $1.1 million during each of the years ended December 31, 2017 and 2016 , and is included in depreciation and amortization with respect to the supply contract and as a component of net revenue with respect to the marketing contract on the accompanying consolidated statements of income and comprehensive income. Amortization expense is estimated to be $7.2 million for each of the years ended December 31, 2019 through 2023

Long-Term Obligations

Long-Term Obligations	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-Term Obligations	Long-Term Obligations DKL Credit Facility At December 31, 2017, the Partnership had a $700.0 million senior secured revolving credit agreement with Fifth Third Bank ("Fifth Third"), as administrative agent, and a syndicate of lenders (the "2014 Facility") with a $100.0 million accordion feature, bearing interest at (i) either a U.S. prime dollar rate or a LIBOR Rate for borrowings denominated in U.S. Dollars, or (ii) either a Canadian dollar prime rate, or a Canadian Dealer Offered Rate, for borrowings denominated in Canadian dollars (in each case plus applicable margins, at the election of the borrowers and as a function of draw down currency). The 2014 Facility had a maturity date of December 30, 2019, and outstanding borrowings at December 31, 2017 were $179.9 million . The obligations under the 2014 Facility were secured by a first priority lien on substantially all of the Partnership's tangible and intangible assets. Additionally, a subsidiary of Delek Holdings provided a limited guaranty of the Partnership's obligations under the 2014 Facility. On September 28, 2018, the Partnership entered into a third amended and restated senior secured revolving credit agreement, which amended and restated the 2014 Facility (hereafter, the "DKL Credit Facility") with Fifth Third Bank, as administrative agent, and a syndicate of lenders. The DKL Credit Facility contains a dual currency borrowing tranche that permits draw downs in U.S. or Canadian dollars. Under the terms of the DKL Credit Facility, among other things, the lender commitments were increased from $700.0 million to $850.0 million . The DKL Credit Facility also contains an accordion feature, whereby the Partnership can increase the size of the credit facility to an aggregate of $1.0 billion , subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. The obligations under the DKL Credit Facility remain secured by first priority liens on substantially all of the Partnership's and its subsidiaries' tangible and intangible assets. Additionally, Delek Marketing continues to provide a limited guaranty of the Partnership's obligations under the DKL Credit Facility. 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 Holdings in favor of Delek Marketing (the "Holdings Note") and (ii) secured by Delek Marketing's pledge of the Holdings Note to the lenders under the DKL Credit Facility. As of December 31, 2018 , the principal amount of the Holdings Note was $102.0 million . The DKL Credit Facility has a maturity date of September 28, 2023 . Borrowings denominated in U.S. dollars bear interest at either a U.S. dollar prime rate, plus an applicable margin, or the London Interbank Offered Rate ("LIBOR"), plus an applicable margin, at the election of the borrowers. Borrowings denominated in Canadian dollars bear interest at either a Canadian dollar prime rate, plus an applicable margin, or the Canadian Dealer Offered Rate, plus an applicable margin, at the election of the borrowers. The applicable margin in each case and the fee payable for the unused revolving commitments vary based upon the Partnership's most recent total leverage ratio calculation delivered to the lenders, as called for and defined under the terms of the DKL Credit Facility. At December 31, 2018 , the weighted average interest rate for our borrowings under the facility was approximately 5.4% . Additionally, the DKL Credit Facility requires us to pay a leverage-ratio dependent quarterly fee on the average unused revolving commitment. As of December 31, 2018 , this fee was 0.50% per year. As of December 31, 2018 , we had $456.7 million of outstanding borrowings under the DKL Credit Facility, with no letters of credit in place. Unused credit commitments under the DKL Credit Facility as of December 31, 2018 were $393.3 million . 6.750% Senior Notes Due 2025 On May 23, 2017, the Partnership and Delek Logistics Finance Corp., a Delaware corporation and a wholly owned subsidiary of the Partnership (“Finance Corp.” and together with the Partnership, the “Issuers”), issued $250.0 million in aggregate principal amount of 6.75% senior notes due 2025 (the “2025 Notes”) at a discount. The 2025 Notes are general unsecured senior obligations of the Issuers. The 2025 Notes are unconditionally guaranteed jointly and severally on a senior unsecured basis by the Partnership's existing subsidiaries (other than Finance Corp., the "Guarantors") and will be unconditionally guaranteed on the same basis by certain of the Partnership’s future subsidiaries. The 2025 Notes rank equal in right of payme nt with all existing and future senior indebtedness of the Issuers, and senior in right of payment to any future subordinated indebtedness of the Issuers. Interest on the 2025 Notes is payable semi-annually in arrears on each May 15 and November 15, commencing November 15, 2017. At any time prior to May 15, 2020, the Issuers may redeem up to 35% of the aggregate principal amount of the 2025 Notes with the net cash proceeds of one or more equity offerings by the Partnership at a redemption price of 106.750% of the redeemed principal amount, plus accrued and unpaid interest, if any, subject to certain conditions and limitations. Prior to May 15, 2020, the Issuers may redeem all or part of the 2025 Notes, at a redemption price of the principal amount, plus accrued and unpaid interest, if any, plus a "make whole" premium, subject to certain conditions and limitations. In addition, beginning on May 15, 2020, th e Issuers may, subject to certain conditions and limitations, redeem all or part of the 2025 Notes at a redemption price of 105.063% of the redeemed principal for the twelve-month period beginning on May 15, 2020, 103.375% for the twelve-month period beginning on May 15, 2021, 101.688% for the twelve-month period beginning on May 15, 2022 and 100.00% beginning on May 15, 2023 and thereafter, plus accrued and unpaid interest, if any. In the event of a change of control, accompanied or followed by a ratings downgrade within a certain period of time, subject to certain conditions and limitations, the Issuers will be obligated to make an offer for the purchase of the 2025 Notes from holders at a price equal to 101% of the principal amount thereof, plus accrued and unpaid interest. In connection with the issuance of the 2025 Notes, the Issuers and the Guarantors entered into a registration rights agreement, whereby the Issuers and the Guarantors were required to exchange the 2025 Notes for new notes with terms substantially identical in all material respects with the 2025 Notes (except the new notes do not contain terms with respect to transfer restrictions). On April 25, 2018, we made an offer to exchange the 2025 Notes and the related guarantees that were validly tendered and not validly withdrawn for an equal principal amount of exchange notes that are freely tradeable, as required under the terms of the original indenture (the "Exchange Offer"). The Exchange Offer expired on May 23, 2018 (the "Expiration Date"). The terms of the exchange notes that were issued as a result of the Exchange Offer (also referred to as the "2025 Notes") are substantially identical to the terms of the original 2025 Notes. As of December 31, 2018 , we had $250.0 million in outstanding principal amount of the 2025 Notes. Outstanding borrowings under the 2025 Notes are net of deferred financing costs and debt discount of $4.8 million and $1.5 million , respectively, as of December 31, 2018 . 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, 2018 (in thousands): 2019 2020 2021 2022 2023 Thereafter Total DKL Credit Facility $ — $ — $ — $ — $ 456,700 $ — $ 456,700 2025 Notes $ — $ — $ — $ — $ — $ 250,000 $ 250,000

Equity

Equity	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity	Equity We had 9,109,807 common limited partner units held by the public outstanding as of December 31, 2018 . Additionally, as of December 31, 2018 , Delek Holdings owned a 61.4% limited partner interest in us, consisting of 15,294,046 common limited partner units and a 94.6% interest in our general partner, which owns the entire 2.0% general partner interest consisting of 498,038 general partner units. Affiliates, who are also members of our general partner's management and board of directors, own the remaining 5.4% interest in our general partner. Equity Activity On February 25, 2016, the requirements under the Partnership Agreement for the conversion of all subordinated units into common units were satisfied, and the subordination period ended. As a result, in the first quarter of 2016, all of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. The conversion did not impact the amount of the cash distribution paid or the total number of the Partnership's outstanding units representing limited partner interests. The table below summarizes the changes in the number of units outstanding from December 31, 2015 through December 31, 2018 (in units). Common - Public Common - Delek Holdings Subordinated General Partner Total Balance at December 31, 2015 9,478,273 2,799,258 11,999,258 495,445 24,772,234 GP units issued to maintain 2% interest — — — 1,057 1,057 Unit-based compensation awards (1) 51,818 — — — 51,818 Delek Holdings unit repurchases from public (266,676 ) 266,676 — — — Subordinated unit conversion — 11,999,258 (11,999,258 ) — — Balance at December 31, 2016 9,263,415 15,065,192 — 496,502 24,825,109 GP units issued to maintain 2% interest — — — 1,102 1,102 Unit-based compensation awards (1) 54,026 — — — 54,026 Delek Holdings unit repurchases from public (228,854 ) 228,854 — — — Balance at December 31, 2017 9,088,587 15,294,046 — 497,604 24,880,237 GP units issued to maintain 2% interest — — — 434 434 Unit-based compensation awards (1) 21,220 — — — 21,220 Balance at December 31, 2018 9,109,807 15,294,046 — 498,038 24,901,891 (1) Unit-based compensation awards are presented net of 598 , 14,053 and 17,276 units withheld for taxes as of December 31, 2018 , 2017 and 2016 , respectively. Issuance of Additional Securities Our Partnership Agreement authorizes us to issue an unlimited number of additional partnership securities for the consideration and on the terms and conditions determined by our general partner without the approval of the unitholders. Costs associated with the issuance of securities are allocated to all unitholders' capital accounts based on their ownership interest at the time of issuance. Allocations of Net Income Our Partnership Agreement contains provisions for the allocation of net income and loss to the unitholders and our general partner. For purposes of maintaining partner capital accounts, the Partnership Agreement specifies that items of income and loss shall be allocated among the partners in accordance with their respective percentage interest. Normal allocations according to percentage interests are made after giving effect to priority income allocations in an amount equal to incentive cash distributions allocated 100% to our general partner. The following table presents the allocation of the general partner's interest in net income (in thousands, except percentage of ownership interest): Year Ended December 31, 2018 2017 2016 Net income attributable to partners $ 90,182 $ 69,409 $ 62,804 Less: General partner's IDRs (24,224 ) (17,389 ) (11,160 ) Net income available to partners $ 65,958 $ 52,020 $ 51,644 General partner's ownership interest 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income 1,319 1,040 1,033 General partner's IDRs 24,224 17,389 11,160 Total general partner's interest in net income $ 25,543 $ 18,429 $ 12,193 Incentive Distribution Rights Our general partner is currently entitled to 2.0% of all quarterly distributions that we make prior to our liquidation. Our general partner has the right, but not the obligation, to contribute up to a proportionate amount of capital to us to maintain its current general partner interest. The general partner’s 2.0% interest in these distributions may be reduced if we issue additional units in the future and our general partner does not contribute a proportionate amount of capital to us to maintain its 2.0% general partner interest. Our general partner also currently holds incentive distribution rights that entitle it to receive increasing percentages, up to a maximum of 48.0% , of the cash we distribute from operating surplus (as defined in our Partnership Agreement) in excess of $0.43125 per unit per quarter. The maximum distribution is 48.0% and does not include any distributions that our general partner or its affiliates may receive on common or general partner units that it owns. The incentive distribution rights held by our general partner currently entitle it to receive the maximum distribution. Cash Distributions Our Partnership Agreement sets forth the calculation to be used to determine the amount and priority of available cash distributions that our limited partner unitholders and general partner will receive. Our distributions earned with respect to a given period are declared subsequent to quarter end. The table below summarizes the quarterly distributions related to our quarterly financial results: Quarter Ended Total Quarterly Distribution Per Limited Partner Unit Total Quarterly Distribution Per Limited Partner Unit, Annualized Total Cash Distribution, including general partner interest and IDRs (in thousands) Date of Distribution Unitholders Record Date December 31, 2016 $ 0.680 $ 2.72 $ 20,537 February 14, 2017 February 3, 2017 March 31, 2017 $ 0.690 $ 2.76 $ 21,024 May 12, 2017 May 5, 2017 June 30, 2017 $ 0.705 $ 2.82 $ 21,783 August 11, 2017 August 4, 2017 September 30, 2017 $ 0.715 $ 2.86 $ 22,270 November 14, 2017 November 7, 2017 December 31, 2017 $ 0.725 $ 2.90 $ 22,777 February 12, 2018 February 2, 2018 March 31, 2018 $ 0.750 $ 3.00 $ 23,997 May 15, 2018 May 7, 2018 June 30, 2018 $ 0.770 $ 3.08 $ 24,984 August 13, 2018 August 3, 2018 September 31, 2018 $ 0.790 $ 3.16 $ 25,960 November 9, 2018 November 2, 2018 December 31, 2018 $ 0.810 $ 3.24 $ 26,949 February 12, 2019 February 4, 2019 The allocation of total quarterly cash distributions made to general and limited partners for the years ended December 31, 2018 , 2017 and 2016 is set forth in the table below. Distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below presents total cash distributions applicable to the period in which the distributions are earned (in thousands, except per unit amounts): Year Ended December 31, 2018 2017 2016 General partner's distributions: General partner's distributions $ 1,553 $ 1,408 $ 1,277 General partner's IDRs 24,224 17,389 11,160 Total general partner's distributions 25,777 18,797 12,437 Limited partners' distributions: Common 76,113 69,057 58,158 Subordinated — — 4,424 Total limited partners' distributions 76,113 69,057 62,582 Total cash distributions $ 101,890 $ 87,854 $ 75,019 Cash distributions per limited partner unit $ 3.120 $ 2.835 $ 2.575

Equity Based Compensation

Equity Based Compensation	12 Months Ended
	Dec. 31, 2018
Share-based Compensation [Abstract]
Equity Based Compensation	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 $0.7 million , $0.7 million and $0.6 million of unit-based compensation expense related to the Partnership during the years ended December 31, 2018 , 2017 and 2016 , respectively. These amounts are included in general and administrative expenses in the accompanying consolidated statements of income and comprehensive income. The fair value of phantom unit awards under the LTIP is determined based on the closing market 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 one - to five -year service periods, unless such awards are amended in accordance with the LTIP. The total fair value of phantom units vested was $0.7 million , $1.7 million and $1.7 million during the years ended December 31, 2018 , 2017 and 2016 , respectively. As of December 31, 2018 , there was $0.3 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 0.4 years. A summary of our unit award activity for the years ended December 31, 2018 , 2017 and 2016 , is set forth below: Number of Phantom Units Weighted-Average Grant Price Non-vested December 31, 2015 145,072 $ 24.76 Granted 12,475 $ 26.05 Vested (69,094 ) $ 24.66 Forfeited (14,500 ) $ 22.65 Non-vested December 31, 2016 73,953 $ 25.49 Granted 10,090 $ 32.2 Vested (68,079 ) $ 24.6 Forfeited — $ — Non-vested December 31, 2017 15,964 $ 33.54 Granted 19,536 $ 28.57 Vested (21,818 ) $ 31.76 Non-vested December 31, 2018 13,682 $ 29.29

Equity Method Investments

Equity Method Investments	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments We have two joint ventures that have constructed separate crude oil pipeline systems and related ancillary assets, which are serving third parties and subsidiaries of Delek Holdings. We own a 50% membership interest in the entity formed with an affiliate of Plains All American Pipeline, L.P. ("CP LLC") to operate one of these pipeline systems and a 33% membership interest in the entity formed with Rangeland Energy II, LLC ("Rangeland Energy") to operate the other pipeline system. During 2018, Rangeland Energy was acquired by Andeavor and the legal entity in which we have an equity investment became Andeavor Logistics RIO Pipeline LLC ("Andeavor Logistics"). The Partnership's investments in these two entities were financed through a combination of cash from operations and borrowings under the 2014 Credit Facility. As of December 31, 2018 and December 31, 2017 , the Partnership's investment balance in these joint ventures was $104.8 million and $106.5 million , respectively. We do not consolidate any part of the assets or liabilities or operating results of our equity method investees. Our share of net income or loss of the investees will increase or decrease, as applicable, the carrying value of our investments in unconsolidated affiliates. With respect to CP LLC and Andeavor Logistics, we determined that these entities do not represent variable interest entities and consolidation is not required. We have the ability to exercise significant influence over each of these joint ventures through our participation in the management committees, which make all significant decisions. However, since all significant decisions require the consent of the other investor(s) without regard to economic interest, we have determined that we have joint control and have applied the equity method of accounting. Our investment in these joint ventures is reflected in our pipelines and transportation segment. Summarized Financial Information Combined summarized financial information for our equity method investees is shown below (in thousands): Year Ended Year Ended December 31, 2018 December 31, 2017 Current assets $ 15,450 $ 12,671 Non-current assets $ 240,852 $ 244,329 Current liabilities $ 4,362 $ 1,798 Year Ended Year Ended Year Ended December 31, 2018 December 31, 2017 December 31, 2016 Revenues $ 35,050 $ 28,805 $ 2,217 Gross profit $ 17,690 $ 13,344 $ (2,048 ) Net Income/loss $ 15,701 $ 10,714 $ (3,641 )

Segment Data

Segment Data	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Segment Data	Segment Data We aggregate our operating segments into two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling: • The assets and investments reported in the pipelines and transportation segment provide crude oil gathering, and crude oil, intermediate and refined products transportation and storage services to Delek Holdings' refining operations and independent third parties. • The wholesale marketing and terminalling segment provides wholesale marketing and terminalling services to Delek Holdings' refining operations and independent third parties. Our operating segments adhere to the accounting policies used for our consolidated financial statements, as described in Note 2 . Our operating segments are managed separately because each segment requires different industry knowledge, technology and marketing strategies. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on segment contribution margin. Segment contribution margin is defined as net revenues less cost of materials and other and operating expenses, excluding depreciation and amortization. The following is a summary of business segment operating performance as measured by contribution margin for the periods indicated (in thousands): Year Ended December 31, 2018 2017 2016 Pipelines and Transportation Net revenues: Affiliate 138,418 $ 109,298 103,749 Third party 15,149 12,431 18,423 Total pipelines and transportation 153,567 121,729 122,172 Cost of materials and other 19,878 18,210 19,425 Operating expenses (excluding depreciation and amortization) 39,934 33,240 29,235 Segment contribution margin $ 93,755 $ 70,279 $ 73,512 Capital spending (1) $ 6,840 $ 14,262 $ 8,478 Wholesale Marketing and Terminalling Net revenues: Affiliate (2) 102,391 46,982 45,815 Third party 401,651 369,364 280,072 Total wholesale marketing and terminalling 504,042 416,346 325,887 Cost of materials and other 409,183 354,680 282,733 Operating expenses (excluding depreciation and amortization) 18,810 10,034 7,963 Segment contribution margin $ 76,049 $ 51,632 $ 35,191 Capital spending (1) $ 4,725 $ 4,141 $ 3,289 Consolidated Net revenues: Affiliate $ 240,809 $ 156,280 $ 149,564 Third party 416,800 381,795 298,495 Total Consolidated 657,609 538,075 448,059 Cost of materials and other 429,061 372,890 302,158 Operating expenses (excluding depreciation and amortization presented below) 58,744 43,274 37,198 Contribution margin 169,804 121,911 108,703 General and administrative expenses 17,166 11,840 10,256 Depreciation and amortization 25,990 21,914 20,813 Loss (gain) on asset disposals 891 (20 ) (16 ) Operating income $ 125,757 $ 88,177 $ 77,650 Capital spending (1) $ 11,565 $ 18,403 $ 11,767 (1) Capital spending excludes transaction costs capitalized in the amount of $0.4 million that relate to the Big Spring Logistic Assets Acquisition for the year ended December 31, 2018 . (2) Affiliate revenue for the wholesale marketing and terminalling segment is presented net of amortization expense pertaining to the Marketing Contract Intangible Acquisition. See Note 3 for additional information. The following table summarizes the total assets for each segment as of December 31, 2018 and 2017 (in thousands). Year Ended December 31, 2018 2017 Pipelines and transportation $ 387,333 $ 349,351 Wholesale marketing and terminalling 237,260 94,179 Total assets $ 624,593 $ 443,530

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments . We apply the provisions of ASC 820, 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 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 to our financial statements 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. Commodity swaps, exchange-traded futures, physical commodity forward purchase and sale contracts are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, spot prices, interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2. The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis at December 31, 2018 and 2017 was as follows: (in thousands): As of December 31, 2018 Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ — $ 186 $ — $ 186 Total assets — 186 — 186 Liabilities Commodity derivatives — (2 ) — (2 ) Net liabilities $ — $ 184 $ — $ 184 As of December 31, 2017 Level 1 Level 2 Level 3 Total Liabilities Commodity derivatives — (1,087 ) — (1,087 ) Net liabilities $ — $ (1,087 ) $ — $ (1,087 ) The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. In the table above, 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 wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and where the legal right of offset exists. As of December 31, 2018 and 2017 , we had cash collateral of $0.4 million and $0.3 million , respectively, netted with the net derivative position of our counterparty. See Note 17

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [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 refined products in the normal course of business. We use derivatives to reduce the impact of market price volatility on our results of operations. Typically, we enter into forward fuel contracts with major financial institutions in which we fix the purchase price of refined grade fuel for a predetermined number of units with fulfillment terms of less than 90 days. The following table presents the fair value of our derivative instruments, as of December 31, 2018 and 2017 . The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including any cash deficit or collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below differ from the amounts presented in our accompanying consolidated balance sheets. During the years ended December 31, 2018 and 2017 , we did not elect hedge accounting treatment for these derivative positions. As a result, all changes in fair value are marked to market in the accompanying consolidated statements of income and comprehensive income. See Note 16 for further information regarding the fair value of derivative instruments. (in thousands) December 31, 2018 December 31, 2017 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives: Commodity derivatives (1) Other current assets $ 186 $ (2 ) $ — $ (1,087 ) Total gross fair value of derivatives 186 (2 ) — (1,087 ) Less: Counterparty netting and cash deficit (collateral) (2) (404 ) (2 ) — (290 ) Total net fair value of derivatives $ 590 $ — $ — $ (797 ) (1) As of December 31, 2018 and 2017 , we had open derivative contracts representing 82,000 barrels and 370,000 barrels, respectively, of refined petroleum products. (2) As of December 31, 2018 and 2017 , we had cash collateral of $0.4 million and $0.3 million , respectively, netted with the net derivative position of our counterparty. Recognized gains (losses) associated with our derivatives for the years ended December 31, 2018 and 2017 were as follows (in thousands): Year Ended December 31, Derivative Type Income Statement Location 2018 2017 2016 Commodity derivatives Cost of materials and other 3,325 (1,550 ) (2,122 )

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes For tax purposes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under our Partnership Agreement. The Partnership is not a taxable entity for federal income tax purposes. While most states do not impose an entity level tax on partnership income, the Partnership is subject to entity level tax in both Tennessee and Texas. The Partnership does not file a separate Texas tax return. Our results of operations are included in Delek Holdings’ consolidated return. However, the provisions of ASC 740 have been followed as if we were a stand-alone entity. As a result, the Partnership must record deferred income taxes for the differences between book and tax bases of its assets and liabilities based on those states' enacted tax rates and laws that will be in effect when the differences are expected to reverse. The total non-current deferred tax assets were $0.3 million and $0.4 million as of December 31, 2018 and 2017 , respectively, and are included in other non-current assets in our accompanying consolidated balance sheets. The majority component of our non-current deferred tax assets as of December 31, 2018 and 2017 was depreciation and amortization. The difference between the actual income tax expense and the tax expense computed by applying the statutory federal income tax rate to income before income taxes is attributable to the following (in thousands): Year Ended December 31, 2018 2017 2016 State income taxes $ 534 (222 ) 121 Other items $ — — (40 ) Income tax expense (benefit) $ 534 $ (222 ) $ 81 Income tax expense (benefit) is as follows (in thousands): Year Ended December 31, 2018 2017 2016 Current $ 382 $ (111 ) $ 254 Deferred $ 152 (111 ) (173 ) Total $ 534 $ (222 ) $ 81 Delek Holdings files a consolidated Texas gross margin tax return, and tax payments for the Partnership are paid by Delek Holdings. Therefore, a portion of the current tax payable is included in accounts receivable/payable from related parties. As of December 31, 2018 and 2017 , income taxes payable of $0.3 million were included in accounts receivable/payable from related parties in the accompanying consolidated balance sheets. Taxes that are determined on a consolidated basis apply the “benefits for loss” allocation method; thus, tax attributes are realized when used in the combined tax return to the extent that they have been subject to a valuation allowance. The consolidated Texas franchise tax return for Delek Holdings, including the Partnership, is currently under examination for tax years 2014 and 2015. No material adjustments have been identified at this time. We recognize accrued interest and penalties related to unrecognized tax benefits as an adjustment to the current provision for income taxes. There were no uncertain tax positions recorded as of December 31, 2018 or 2017 , and there were no interest or penalties recognized related to uncertain tax positions for the years ended December 31, 2018 , 2017 or 2016

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [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 financial statements. See "Crude Oil Releases" below for discussion of an enforcement action. Environmental Health and Safety We are subject to extensive federal, state and local environmental and safety laws and regulations enforced by various agencies, including the Environmental Protection Agency (the "EPA"), the United States Department of Transportation, the Occupational Safety and Health Administration, as well as numerous state, regional and local environmental, safety and pipeline agencies. These laws and regulations govern the discharge of materials into the environment, waste management practices and pollution prevention measures, as well as the safe operation of our pipelines and the safety of our workers and the public. Numerous permits or other authorizations are required under these laws and regulations for the operation of our terminals, pipelines, saltwells, trucks 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 handled, used, released or disposed of, transported, 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 we expect that there 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 to comply with existing and new requirements, as well as evolving interpretations and more strict enforcement of existing laws and regulations. Releases of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured, or is not a reimbursable event under the Omnibus Agreement, subject us to substantial expenses, including costs to respond to, contain and remediate a release, to comply with applicable laws and regulations and to resolve claims by third parties for personal injury, property damage or natural resources damages. Crude Oil Releases We have experienced several crude oil releases involving our assets, including, but not limited to, the following releases: • On December 25, 2018 a release of an undetermined quantity of crude oil occurred on one of our gathering lines near Norphlet, Arkansas (the "Norphlet Release"); • On December 13, 2018 a release of an undetermined quantity of crude oil occurred on one of our gathering lines near Smackover, Arkansas (the "Smackover-Langley Release"); • In November 2018, a release of approximately 20 barrels of crude oil occurred near Smackover, Arkansas; • On March 15, 2018 a release of approximately 10 barrels of crude oil occurred on one of our gathering lines located on property owned by Clean Harbors, Inc. in El Dorado, Arkansas; • In February 2018, a release of approximately 50 barrels of crude oil occurred from a line near one of our storage facilities located south of El Dorado, Arkansas; • In February 2018, a release of approximately 250 barrels of crude oil, occurred from our SALA Gathering System near Urbana, Arkansas Station; and • In March 2013, a release of approximately 5,900 barrels of crude oil, the majority of which was contained on-site, occurred from a pumping facility at our Magnolia Station located west of the El Dorado Refinery (the "Magnolia Release"). Cleanup operations and site maintenance and remediation efforts on these and other releases have been substantially completed, with the exception of the Smackover-Langley Release and the Norphlet Release, which are expected to be remediated in the third and first quarters of 2019, respectively. However, regulatory authorities could require additional remediation based on the results of our remediation efforts. We may incur additional expenses as a result of further scrutiny by regulatory authorities and continued compliance with laws and regulations to which our assets are subject. As of December 31, 2018 , we have accrued $1.5 million and $0.5 million for the Smackover-Langley Release and the Norphlet Release, respectively, for remediation and other such matters. Expenses incurred for the remediation of these crude oil releases are included in operating expenses in our consolidated statements of income and comprehensive income and are subsequently reimbursed by Delek Holdings pursuant to the terms of the Omnibus Agreement. Reimbursements are recorded as a reduction to operating expense. We do not believe the total costs associated with these events, whether alone or in the aggregate, including any fines or penalties and net of available insurance reimbursement, will have a material adverse effect upon our business, financial condition or results of operations as we are reimbursed by Delek Holdings for such costs. During the year ended December 31, 2018 , we recorded approximately $0.4 million of expense, which is net of total reimbursable costs from Delek Holdings pursuant to the terms of the Omnibus Agreement of $9.8 million for the year ended December 31, 2018 to cover the cost of certain asset failures that occurred in 2018 . The United States Department of Justice (the "DOJ"), on behalf of the EPA and the state of Arkansas, on behalf of the Arkansas Department of Environmental Quality, have been pursuing an enforcement action against the Partnership with regard to potential violations of the Clean Water Act and certain state laws arising from the Magnolia Release since June 2015. On July 13, 2018, the DOJ and the State of Arkansas filed a civil action against two of the Partnership's wholly-owned subsidiaries, Delek Logistics Operations, LLC and SALA Gathering Systems LLC, in the United States District Court for the Western District of Arkansas. On December 12, 2018, the claims against the Partnership were resolved and an additional demand for a compliance audit at the Magnolia terminal was abandoned pursuant to payment of monetary penalties and other relief. As of December 31, 2018 , we have accrued $2.2 million for the Magnolia Release, which represents the full settlement amount for these proceedings. The accrual is recorded in pipeline release liabilities in our consolidated balance sheet. Contracts and Agreements The majority of the petroleum products we sold in west Texas prior to December 31, 2017 were purchased from Noble Petro, Inc. ("Noble Petro"). Under the terms of a supply contract with Noble Petro that expired on December 31, 2017 , we purchased petroleum products at the Abilene, Texas terminal, which we own, for sales and exchanges with third parties at the Abilene, Texas and San Angelo, Texas terminals. We leased the Abilene and San Angelo, Texas terminals to Noble Petro under a separate Terminal and Pipeline Lease and Operating Agreement, that expired on December 31, 2017 . During 2018, we purchased spot barrels from various third parties and from Delek Holdings for sale to wholesale customers in west Texas. Letters of Credit As of December 31, 2018 , we had no letters of credit in place under the DKL Credit Facility. 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, 2018 , 2017 and 2016 totaled $6.2 million , $5.6 million and $5.7 million , respectively. The following is an estimate of our future minimum lease payments for operating leases having remaining noncancelable terms in excess of one year as of December 31, 2018 (in thousands): 2019 $ 5,755 2020 5,659 2021 5,337 2022 5,031 2023 2,429 Thereafter 8 Total future minimum rentals $ 24,219

Selected Quarterly Financial Da

Selected Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2018
Selected Quarterly Financial Information [Abstract]
Selected Quarterly Financial Data	Selected Quarterly Financial Data (Unaudited) Quarterly financial information for the years ended December 31, 2018 and 2017 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). For the Three Month Periods Ended March 31, 2018 June 30, 2018 September 30, 2018 December 31, 2018 Net revenues $ 167,921 $ 166,280 $ 164,110 $ 159,298 Operating income $ 27,277 $ 34,710 $ 32,624 $ 31,147 Net income $ 19,995 $ 25,582 $ 23,326 $ 21,280 Limited partners' interest in net income $ 14,365 $ 19,370 $ 16,690 $ 14,215 Net income per limited partner unit: Common (basic) $ 0.59 $ 0.79 $ 0.68 $ 0.58 Common (diluted) $ 0.59 $ 0.79 $ 0.68 $ 0.58 For the Three Month Periods Ended March 31, 2017 June 30, 2017 September 30, 2017 December 31, 2017 Net revenues $ 129,473 $ 126,769 $ 130,626 $ 151,207 Operating income $ 18,472 $ 23,371 $ 22,636 $ 23,698 Net income $ 14,595 $ 18,977 $ 16,923 $ 18,914 Limited partners' interest in net income $ 10,486 $ 14,425 $ 12,178 $ 13,891 Net income per limited partner unit: Common (basic) $ 0.43 $ 0.59 $ 0.50 $ 0.57 Common (diluted) $ 0.43 $ 0.59 $ 0.50 $ 0.57

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2018
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Distribution Declaration On January 24, 2019 , our general partner's board of directors declared a quarterly cash distribution of $0.810 per unit, paid on February 12, 2019 , to unitholders of record on February 4, 2019

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Organization	Organization As used in this report, the terms "Delek Logistics Partners, LP," the "Partnership," "we," "us," or "our" may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole.
Basis of Presentation	Basis of Presentation Our consolidated financial statements include the accounts of the Partnership and its subsidiaries. All intercompany accounts and transactions have been eliminated. 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.
Segment Reporting	Segment Reporting We are an energy business focused on crude oil, intermediate and refined products pipeline and storage activities and wholesale marketing, terminalling and offloading activities. Management reviews operating results in two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. The pipelines and transportation segment provides crude oil gathering, transportation and storage services to Delek Holdings' refining operations and independent third parties. The wholesale marketing and terminalling segment provides marketing, wholesale marketing and terminalling services to Delek Holdings' 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 revenues less cost of materials and other and operating expenses, excluding depreciation and amortization. Segment reporting is more fully discussed in Note 15
Cash and Cash Equivalents	Cash and Cash EquivalentsWe maintain cash and cash equivalents in accounts with large, U.S. financial institutions. Any highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents.
Accounts Receivable	Accounts ReceivableAccounts 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.
Inventory	InventoryInventory consists of refined products, which are stated at the lower of cost or net realizable value, with cost determined on a first-in, first-out ("FIFO") basis
Property, Plant and Equipment	Property, Plant and Equipment Assets acquired in conjunction with business acquisitions are recorded at estimated fair market value in accordance with the purchase method of accounting as prescribed in Accounting Standards Codification ("ASC") 805, Business Combinations ("ASC 805"). Other acquisitions of property and equipment are carried at cost. Acquisitions of net assets that do not constitute a business are accounted for by allocating the cost of the acquisition to individual assets acquired and liabilities assumed on relative fair value basis and shall not give rise to goodwill as prescribed in ASC 805. 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 Buildings and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15
Intangible Assets	Intangible Assets Intangible assets consist of a long-term supply contract, indefinite-lived rights of way and a long-term marketing agreement. We amortize the definite-lived long-term supply contract on a straight-line basis over the estimated useful life of 11.5
Property, Plant and Equipment and Intangibles Impairment	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
Goodwill and Potential Impairment	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. Goodwill is reviewed at least annually for impairment, or more frequently if indicators of impairment exist, such as disruptions in our business, unexpected significant declines in operating results, or a sustained market capitalization decline. Goodwill is evaluated for impairment by comparing the carrying amount of the reporting unit to its estimated fair value. Prior to the adoption of Accounting Standard Update ("ASU") 2017-04, Simplifying the Test for Goodwill Impairment, i
Equity Method Investments	Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of influence over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Equity investments for which we determine we have significant influence are accounted for as equity method investments. Amounts recognized for equity method investments are included in equity method investments in our consolidated balance sheets and adjusted for our share of the net earnings and losses of the investee and cash distributions, which are separately stated in our consolidated statements of income and comprehensive income and our consolidated statements of cash flows. We evaluate our equity method investments presented for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary.
Derivatives	Derivatives We record all derivative financial instruments, including forward fuel contracts, at estimated fair value in accordance with the provisions of ASC 815, Derivatives and Hedging ("ASC 815"). Changes in the fair value of the derivative instruments are recognized in operations, unless we elect to apply the hedge accounting treatment permitted under the provisions of ASC 815 allowing such changes to be classified as other comprehensive income for cash flow hedges. We validate the fair value of all derivative financial instruments on a periodic basis, utilizing exchange pricing and/or price index developers, such as Platts or Argus. During the years ended December 31, 2018 , 2017 and 2016 , we did not elect to apply hedge accounting treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of income and comprehensive income. Our policy under the guidance of ASC 815-10-45, Derivatives and Hedging—Other Presentation Matters ("ASC 815-10-45"), is to net the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and offset these values against any cash collateral associated with these derivative positions. See Note 17
Fair Value of Financial Instruments	Fair Value of Financial Instruments The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments ("ASC 825"). We apply the provisions of ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), in our presentation and disclosures regarding fair value, which pertain to certain financial assets and liabilities measured at fair value in the balance sheet on a recurring basis. ASC 820 defines fair value, establishes a framework for measuring fair value and expands disclosures about such measurements that are permitted or required under other accounting pronouncements. See Note 16 for further discussion. We apply the provisions of ASC 825 as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. By electing the fair value option in conjunction with a derivative, an entity can achieve an accounting result similar to a fair value hedge without having to comply with complex hedge accounting rules. As of December 31, 2018 and 2017
Self Insurance Reserves	Self-Insurance ReservesWe have no employees. Rather, we are managed by the directors and officers of our general partner. However, Delek Holdings employees providing services to the Partnership are covered under Delek Holdings’ insurance programs. Delek Holdings has workers' compensation and liability insurance with varying retentions and deductibles with limits that management considers adequate.
Environmental Expenditures	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	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.Asset Retirement ObligationsWe 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.
Revenue Recognition, Cost of Materials and Operating Expenses -front Payments to Customer, and Sales, Use and Excise Taxes	Revenue Recognition Revenue is measured based on consideration specified in a contract with a customer. The Partnership recognizes revenue when it satisfies a performance obligation by transferring control over a product or by providing services to a customer. The adoption of ASC 606, Revenue from Contracts with Customers ("ASC 606"), did not materially change our revenue recognition patterns, which are described below. The principles for recognizing revenue as codified in ASC 605, Revenue Recognition ("ASC 605"), were applied during the years ended December 31, 2017 and 2016 . No restatements to revenues or expenses were required to be made to our consolidated statements of income, as we applied the modified retrospective transition method in adopting ASC 606, as described below under "—New Accounting Pronouncements Adopted During 2018— ASU 2014-09, Revenue - Revenue from Contracts with Customers ." Revenues for products sold are generally recognized upon delivery of product, which is when title and control of the product is transferred. Transaction prices for these products are typically at market rates for the product at the time of delivery. Service revenues are recognized as crude oil, intermediate and refined products are shipped through, delivered by or stored in our pipelines, trucks, terminals and storage facility assets, as applicable. We do not recognize product revenues for these services, as the product does not represent a promised good in the context of ASC 606. All service revenues are based on regulated tariff rates or contractual rates. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. Certain agreements for gathering, transportation, storage, terminalling, and offloading with Delek Holdings are considered operating leases under ASC 840, Leases ("ASC 840"). We identified the separate lease and service components of our revenues under these leases and applied ASC 606 only to the service component, while the lease component continued to be accounted for under ASC 840. Refer to Note 5 for further information. Cost of Materials and Other and Operating Expenses Cost of materials and other includes (i) all costs of purchased refined products, additives and related transportation of such products, (ii) costs associated with the operation of our trucking assets, which primarily include allocated employee costs and other costs related to fuel, truck leases and repairs and maintenance, (iii) the cost of pipeline capacity leased from a third-party, and (iv) gains and losses related to our commodity hedging activities. Operating expenses include the costs associated with the operation of owned terminals and pipelines and terminalling expense at third-party locations, excluding depreciation and amortization. These costs primarily include outside services, allocated employee costs, repairs and maintenance costs and energy and utility costs. Operating expenses related to the wholesale business are excluded from cost of sales because they primarily relate to costs associated with selling the products through our wholesale business. Depreciation and amortization is separately presented in our statement of income and disclosed by reportable segment in Note 15 We record all up-front payments to customers in accordance with the provisions of ASC 606. We evaluate the nature of each payment, the rights and obligations under the related contract, and whether the payment meets the definition of an asset. When an asset is recognized for an up-front payment to a customer, the asset is amortized, as a reduction of revenue, in a manner that reflects the pattern and period over which the asset is expected to provide benefit. Sales, Use and Excise Taxes Prior to the adoption of ASC 606, the Partnership's policy was to exclude sales, use and excise taxes from revenue when we are an agent of the taxing authority, in accordance with the applicable guidance in ASC 605. Upon the adoption of ASC 606, we made the accounting policy election to exclude from revenue all taxes assessed by a governmental authority, including sales, use and excise taxes, that are both imposed on and concurrent with a specific revenue-producing transaction and collected on behalf of a customer.
Deferred Financing Costs	Deferred Financing Costs Deferred financing costs are included in other non-current assets in the accompanying consolidated balance sheets and represent expenses related to issuing and amending our revolving credit facility. Deferred financing costs associated with our 6.750%
Operating Leases	Operating LeasesWe lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term, to renew the leases. None of these lease arrangements include fixed rental rate increases.
Income Taxes	Income Taxes We are not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of these income taxes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under the First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement"). We are subject to income taxes in certain states that do not follow the federal tax treatment of Partnerships. These taxes are accounted for under the provisions of ASC 740, Income Taxes ("ASC 740"). This statement generally requires the Partnership 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.
Equity based Compensation	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. The fair value of our phantom units is determined based on the closing market 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 one- to five-year service periods, unless such awards are amended in accordance with the LTIP (as defined in Note 13
Net income per Limited Partner Unit	Net Income per Limited Partner Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and incentive distribution rights ("IDRs"). The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs, by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our Partnership Agreement. The weighted-average number of common units reflects the conversion of the subordinated units to common units on February 25, 2016. See Notes 6 and 12 for further discussion. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. As of December 31, 2018
New Accounting Pronouncements Adopted and Not Yet Adopted	New Accounting Pronouncements Adopted During 2018 ASU 2017-09, Stock Compensation - Scope of Modification Accounting In May 2017, the FASB issued guidance that clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as modifications. The modification accounting guidance applies if the value, vesting conditions or classification of the award changes. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. This guidance should be applied prospectively to an award modified on or after the adoption date. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations. ASU 2017-05, Other Income - Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets In February 2017, the FASB issued guidance clarifying the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The amendments in this guidance should be applied using either i) a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption or ii) a retrospective basis to each period presented in the financial statements. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We adopted this guidance on January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations. ASU 2017-04, Intangible - Simplifying the Test for Goodwill Impairment In January 2017, the FASB issued guidance concerning the goodwill impairment test that eliminates Step 2, which required a comparison of the implied fair value of goodwill of the reporting unit with the carrying amount of that goodwill for that reporting unit. It also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative assessment, to perform Step 2 of the goodwill impairment test. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. This guidance is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. As permitted under Accounting Standards Update 2017-04, we adopted this guidance in the fourth quarter of 2018 in connection with our 2018 goodwill impairment tests. The adoption did not have a material impact on our business, financial condition or results of operations. ASU 2016-15, Statement of Cash Flow - Classification of Certain Cash Receipts and Cash Payments In August 2016, the FASB issued guidance that clarifies eight cash flow classification issues pertaining to cash receipts and cash payments. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations, except for reclassifications of certain distributions received from equity method investees, due to us making an accounting policy election to classify distributions received from equity method investees using the cumulative earnings approach. Under this approach, distributions received are considered returns on investment and classified as cash inflows from operating activities, unless the investor’s cumulative distributions received less distributions received in prior periods that were determined to be returns of investment exceed cumulative equity in earnings (as adjusted for amortization of basis differences) recognized by the investor. When such an excess occurs, the current-period distribution up to this excess should be considered a return of investment and classified as cash inflows from investing activities. This resulted in a reclassification of $0.8 million of distributions received in the year ended December 31, 2017 from the line item entitled dividends from equity method investments in net cash provided by (used in) operating activities to the line item entitled distributions from equity method investments in net cash provided by (used in) investing activities in the consolidated statements of cash flows. ASU 2016-07, Investment - Simplifying the Transition to the Equity Method of Accounting In January 2016, the FASB issued guidance that affects the accounting for equity investments, financial liabilities accounted for under the fair value option and the presentation and disclosure requirements for financial instruments. Under the new guidance, all equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) will generally be measured at fair value through earnings. There will no longer be an available-for-sale classification for equity securities with readily determinable fair values. For financial liabilities when the fair value option has been elected, changes in fair value due to instrument-specific credit risk will be recognized separately in other comprehensive income. It will require public business entities to use the exit price notion when measuring the fair value of financial instruments for disclosure purposes and separate presentation of financial assets and financial liabilities by measurement category and form of financial asset, and will eliminate the requirement for public business entities to disclose the method and significant assumptions used to estimate the fair value that is required to be disclosed for financial instruments measured at amortized cost. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We adopted this guidance on January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations. ASU 2014-09, Revenue - Revenue from Contracts with Customers In May 2014, the FASB issued guidance as codified in Accounting Standards Codification ("ASC") 606, “Revenue from Contracts with Customers ("ASC 606),” to clarify the principles for recognizing revenue. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The guidance also requires improved interim and annual disclosures that enable the users of financial statements to better understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period, and can be adopted retrospectively. We adopted this guidance on January 1, 2018, using the modified retrospective transition method applied to contracts which were not completed as of January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations. New Accounting Pronouncements Not Yet Adopted ASU 2018-13, Fair Value Measurement - Changes to the Disclosure Requirements for Fair Value Measurement In August 2018, the Financial Accounting Standards Board (the "FASB") issued guidance related to disclosure requirements for fair value measurements. The pronouncement eliminates, modifies and adds disclosure requirements for fair value measurements. The pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted. We expect to adopt this guidance on or before the effective date and do not expect adopting this new guidance will have a material impact on our business, financial condition or results of operations. ASU 2017-12, Derivatives and Hedging - Targeted Improvements to Accounting for Hedging Activities In August 2017, the FASB issued guidance to better align financial reporting for hedging activities with the economic objectives of those activities for both financial (e.g., interest rate) and commodity risks. The guidance was intended to create more transparency in the presentation of financial results, both on the face of the financial statements and in the footnotes, and simplify the application of hedge accounting guidance. This guidance is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Companies are required to apply the guidance on a modified retrospective transition method in which the cumulative effect of the change will be recognized within equity in the consolidated balance sheet as of the date of adoption. Early adoption is permitted, including in an interim period. If a company early adopts in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes the interim period. We expect to adopt this guidance on or before the effective date and are currently evaluating the impact that adopting this new guidance will have on our business, financial condition and results of operations. ASU 2016-02, Leases In February 2016, the FASB issued guidance that requires the recognition of a lease liability and a right-of-use asset, initially measured at the present value of the lease payments, in the statement of financial condition for all leases with terms longer than one year. The guidance was subsequently amended to consider the impact of practical expedients and provide additional clarifications. The guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We plan to adopt the new lease standard on January 1, 2019. We plan to elect the package of practical expedients which, among other things, allows us to carry forward the historical lease classification. We plan to also elect the practical expedient not to separate lease and non-lease components, which allows us to combine the components if certain criteria are met. Further, we plan to elect the optional transition method, which allows us to recognize a cumulative-effect adjustment to the opening balance sheet of retained earnings at the date of adoption and to not recast our comparative periods. We do not plan to elect the hindsight practical expedients, which would have allowed us to use hindsight in determining the reasonably certain lease term.

Accounting Policies (Tables)

Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Property, Plant and Equipment	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 Buildings and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 December 31, 2018 2017 Land $ 4,458 $ 4,440 Building and building improvements 3,695 2,804 Pipelines, tanks and terminals 410,154 314,251 Asset retirement obligation assets 2,073 2,073 Other equipment 15,838 14,650 Construction in process 16,528 28,961 452,746 367,179 Less: accumulated depreciation (140,184 ) (112,111 ) $ 312,562 $ 255,068 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2018 and 2017 are as follows (in thousands): As of and For the Year Ended December 31, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 361,702 $ 91,044 $ 452,746 Less: accumulated depreciation (106,971 ) (33,213 ) (140,184 ) Property, plant and equipment, net $ 254,731 $ 57,831 $ 312,562 Depreciation expense $ 21,115 $ 4,786 $ 25,901 As of and For the Year Ended December 31, 2017 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 300,134 $ 67,045 $ 367,179 Less: Accumulated depreciation (84,435 ) (27,676 ) (112,111 ) Property, plant and equipment, net $ 215,699 $ 39,369 $ 255,068 Depreciation expense $ 17,268 $ 3,583 $ 20,851
Schedule of Change in Asset Retirement Obligation	The reconciliation of the beginning and ending carrying amounts of asset retirement obligations as of December 31, 2018 and 2017 is as follows (in thousands): December 31, 2018 2017 Beginning balance $ 4,064 $ 3,772 Liabilities acquired 768 — Accretion expense 359 292 Ending balance $ 5,191 $ 4,064

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The allocation of the relative fair value assigned to property, plant and equipment and intangible assets amounted to $6.4 million and $2.6 million

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Commercial Agreements	Our material commercial agreements with Delek Holdings 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 (2) : Crude Oil Pipelines (non-gathered) November 2012 5 / 15 Crude oil and refined products transportation 46,000 (3) $0.99 (4) Refined Products Pipelines November 2012 5 / 15 40,000 $0.12 SALA Gathering System November 2012 5 / 15 Crude oil gathering 14,000 $2.66 (4) East Texas Crude Logistics System (2) : Crude Oil Pipelines November 2012 5 / 15 Crude oil transportation and storage 35,000 $0.47 (5) Storage November 2012 5 / 15 N/A $291,220/month East Texas Marketing November 2012 10 (6) Marketing products for Tyler Refinery 50,000 $0.80 (6) Big Sandy Terminal: (2) (7) Refined Products Transportation November 2012 5 / 15 Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery 5,000 $0.58 Terminalling November 2012 5 / 15 5,000 $0.58 Storage November 2012 5 / 15 N/A $58,192/month Tyler Throughput and Tankage (2) : Refined Products Throughput July 2013 8/ 16 Dedicated Terminalling and storage 50,000 $0.37 Storage July 2013 8/ 16 N/A $871,336/month Memphis Pipeline October 2013 5 Refined Products Transportation 10,959 $1.41 El Dorado Throughput and Tankage (2) : Refined Products Throughput February 2014 8/ 16 Dedicated terminalling and storage 11,000 $0.53 Storage February 2014 8/ 16 N/A $1,363,985/month El Dorado Assets Throughput: Light Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (8) $1.05 Heavy Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (8) $2.36 Pipelines, Storage and Throughput Facilities Agreement (Big Spring): Crude Oil and Refined Products Throughput March 1, 2018 10/15 Pipeline throughput 104,300 0.05 Rail Offloading March 1, 2018 10/15 Offloading services 4,500 0.4 Terminalling March 1, 2018 10/15 Dedicated Terminalling 29,250 0.66 Storage March 1, 2018 10/15 Storage NA $1,374,630/month Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (/bbl) Asphalt Services Agreement (Big Spring): Terminalling March 1, 2018 10/15 Dedicated Asphalt Terminalling and Storage 1,020 to 2,380 based on seasonality 8.3 Storage March 1, 2018 10/15 N/A $456,490/month Marketing Agreement (Big Spring): Marketing Services March 1, 2018 10/15 Dedicated Marketing and Selling 65,000 $0.50 - $0.71 (1) Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof. (2) The current term of the agreement was extended through March 31, 2024 in connection with the amendment and restatement of the DKL Credit Facility (as defined in Note 11 ). While the current terms of the agreement were extended, the upcoming renewal terms were reduced. Therefore, the overall duration of the maximum term above remains unchanged. (3) Excludes volumes gathered on the SALA Gathering System. (4) 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. (5) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.700 /bbl. (6) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.750 /bbl. Following the primary term, the marketing agreement automatically renews for successive one-year term, unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. The initial primary term for the marketing agreement has been extended through 2027. (7) On July 19, 2013, we acquired the Hopewell Pipeline in order to effectively connect it with the Big Sandy Pipeline and thereby return the Big Sandy Terminal to operation. In connection with the acquisition, on July 25, 2013, we and Delek Holdings 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 November 2012. (8) The throughput agreement provides for a minimum throughput fee of $1.5 million
Schedule of Related Party Transactions	A summary of revenue, purchases from affiliates and expense transactions with Delek Holdings and its affiliates are as follows (in thousands): Year Ended December 31, 2018 2017 2016 Revenues $ 240,809 $ 156,280 $ 149,564 Purchases from Affiliates $ 349,089 $ 54,982 $ 32,514 Operating and maintenance expenses $ 36,182 $ 29,483 $ 27,668 General and administrative expenses $ 8,250 $ 7,492 $ 6,254

Revenues (Tables)

Revenues (Tables)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue for each reportable segment for the periods indicated (in thousands): Year Ended December 31, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 15,149 $ 870 $ 16,019 Service Revenue - Affiliate (1) 93,300 53,750 147,050 Product Revenue - Third Party — 400,781 400,781 Product Revenue - Affiliate — 35,252 35,252 Lease Revenue - Affiliate 45,118 13,389 58,507 Total Revenue $ 153,567 $ 504,042 $ 657,609 (1) Net of $6.0 million
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	Our unfulfilled performance obligations as of December 31, 2018 were as follows (in thousands): 2019 168,315 2020 167,965 2021 167,620 2022 166,587 2023 and thereafter 474,200 Total expected revenue on remaining performance obligations $ 1,144,687

Net Income Per Unit (Tables)

Net Income Per Unit (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Net Income Per Unit	The date of distribution for the distributions earned during the period ended December 31, 2018 is February 12, 2019 . The calculation of net income per unit is as follows (dollars in thousands, except per unit amounts): Year Ended December 31, 2018 2017 2016 Net income attributable to partners $ 90,182 $ 69,409 $ 62,804 Less: General partner's distribution (including IDRs) (1) 25,777 18,797 12,437 Less: Limited partners' distribution 76,113 69,057 58,158 Less: Subordinated partner's distribution — — 4,424 Distributions in excess of earnings $ (11,708 ) $ (18,445 ) $ (12,215 ) General partner's earnings: Distributions (including IDRs) (1) $ 25,777 $ 18,797 $ 12,437 Allocation of distributions in excess of earnings (234 ) (368 ) (244 ) Total general partner's earnings $ 25,543 $ 18,429 $ 12,193 Limited partners' earnings on common units: Distributions $ 76,113 $ 69,057 $ 58,158 Allocation of distributions in excess of earnings (11,474 ) (18,077 ) (11,489 ) Total limited partners' earnings on common units $ 64,639 $ 50,980 $ 46,669 Limited partners' earnings on subordinated units: Distributions $ — $ — $ 4,424 Allocation of (distributions) earnings excess — — (482 ) Total limited partner's earnings on subordinated units $ — $ — $ 3,942 Weighted average limited partner units outstanding (2) : Common units - (basic) 24,390,286 24,348,063 22,490,264 Common units - (diluted) 24,396,881 24,376,972 22,558,717 Subordinated units - Delek Holdings (basic and diluted) (3) — — 1,803,167 Net income per limited partner unit (2) : Common - (basic) $ 2.65 $ 2.09 $ 2.08 Common - (diluted) (4) $ 2.65 $ 2.09 $ 2.07 Subordinated - (basic and diluted) $ — $ — $ 2.19 (1) General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs. (2) We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflects the conversion of the subordinated units to common units on February 25, 2016. (3) On February 25, 2016, all of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. Distributions and the Partnership's net income were allocated to the subordinated units through February 24, 2016. (4) Outstanding common unit equivalents totaling 1,776 and 4,240 were excluded from the diluted earnings per unit calculation for the years ended December 31, 2018 and 2016 , respectively, as these common unit equivalents did not have a dilutive effect under the treasury stock method. There were no outstanding common unit equivalents excluded from the diluted earnings per unit calculation during the year ended December 31, 2017

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	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 Buildings and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 December 31, 2018 2017 Land $ 4,458 $ 4,440 Building and building improvements 3,695 2,804 Pipelines, tanks and terminals 410,154 314,251 Asset retirement obligation assets 2,073 2,073 Other equipment 15,838 14,650 Construction in process 16,528 28,961 452,746 367,179 Less: accumulated depreciation (140,184 ) (112,111 ) $ 312,562 $ 255,068 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2018 and 2017 are as follows (in thousands): As of and For the Year Ended December 31, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 361,702 $ 91,044 $ 452,746 Less: accumulated depreciation (106,971 ) (33,213 ) (140,184 ) Property, plant and equipment, net $ 254,731 $ 57,831 $ 312,562 Depreciation expense $ 21,115 $ 4,786 $ 25,901 As of and For the Year Ended December 31, 2017 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 300,134 $ 67,045 $ 367,179 Less: Accumulated depreciation (84,435 ) (27,676 ) (112,111 ) Property, plant and equipment, net $ 215,699 $ 39,369 $ 255,068 Depreciation expense $ 17,268 $ 3,583 $ 20,851

Other Intangible Assets (Tables

Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2018
Other Intangible Assets Disclosure [Abstract]
Schedule of Intangible Assets	Our identifiable intangible assets are as follows (in thousands): Useful Accumulated As of December 31, 2018 Life Gross Amortization Net Intangible assets subject to amortization: Supply contract 11.5 $ 12,227 $ (12,227 ) $ — Marketing contract 20 $ 144,219 $ (6,009 ) 138,210 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 15,828 15,828 Total $ 172,274 $ (18,236 ) $ 154,038 Useful Accumulated As of December 31, 2017 Life Gross Amortization Net Intangible assets subject to amortization: Supply contract 11.5 $ 12,227 $ (12,138 ) $ 89 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 15,828 15,828 Total $ 28,055 $ (12,138 ) $ 15,917

Long-Term Obligations (Tables)

Long-Term Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Schedule of Maturities of Long-term Debt	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, 2018 (in thousands): 2019 2020 2021 2022 2023 Thereafter Total DKL Credit Facility $ — $ — $ — $ — $ 456,700 $ — $ 456,700 2025 Notes $ — $ — $ — $ — $ — $ 250,000 $ 250,000

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Schedule of Capital Units	The table below summarizes the changes in the number of units outstanding from December 31, 2015 through December 31, 2018 (in units). Common - Public Common - Delek Holdings Subordinated General Partner Total Balance at December 31, 2015 9,478,273 2,799,258 11,999,258 495,445 24,772,234 GP units issued to maintain 2% interest — — — 1,057 1,057 Unit-based compensation awards (1) 51,818 — — — 51,818 Delek Holdings unit repurchases from public (266,676 ) 266,676 — — — Subordinated unit conversion — 11,999,258 (11,999,258 ) — — Balance at December 31, 2016 9,263,415 15,065,192 — 496,502 24,825,109 GP units issued to maintain 2% interest — — — 1,102 1,102 Unit-based compensation awards (1) 54,026 — — — 54,026 Delek Holdings unit repurchases from public (228,854 ) 228,854 — — — Balance at December 31, 2017 9,088,587 15,294,046 — 497,604 24,880,237 GP units issued to maintain 2% interest — — — 434 434 Unit-based compensation awards (1) 21,220 — — — 21,220 Balance at December 31, 2018 9,109,807 15,294,046 — 498,038 24,901,891 (1) Unit-based compensation awards are presented net of 598 , 14,053 and 17,276 units withheld for taxes as of December 31, 2018 , 2017 and 2016
Schedule of Calculation of Net Income Applicable to Partners	The following table presents the allocation of the general partner's interest in net income (in thousands, except percentage of ownership interest): Year Ended December 31, 2018 2017 2016 Net income attributable to partners $ 90,182 $ 69,409 $ 62,804 Less: General partner's IDRs (24,224 ) (17,389 ) (11,160 ) Net income available to partners $ 65,958 $ 52,020 $ 51,644 General partner's ownership interest 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income 1,319 1,040 1,033 General partner's IDRs 24,224 17,389 11,160 Total general partner's interest in net income $ 25,543 $ 18,429 $ 12,193
Schedule of Distributions Made to Members or Limited Partners, by Distribution	The table below summarizes the quarterly distributions related to our quarterly financial results: Quarter Ended Total Quarterly Distribution Per Limited Partner Unit Total Quarterly Distribution Per Limited Partner Unit, Annualized Total Cash Distribution, including general partner interest and IDRs (in thousands) Date of Distribution Unitholders Record Date December 31, 2016 $ 0.680 $ 2.72 $ 20,537 February 14, 2017 February 3, 2017 March 31, 2017 $ 0.690 $ 2.76 $ 21,024 May 12, 2017 May 5, 2017 June 30, 2017 $ 0.705 $ 2.82 $ 21,783 August 11, 2017 August 4, 2017 September 30, 2017 $ 0.715 $ 2.86 $ 22,270 November 14, 2017 November 7, 2017 December 31, 2017 $ 0.725 $ 2.90 $ 22,777 February 12, 2018 February 2, 2018 March 31, 2018 $ 0.750 $ 3.00 $ 23,997 May 15, 2018 May 7, 2018 June 30, 2018 $ 0.770 $ 3.08 $ 24,984 August 13, 2018 August 3, 2018 September 31, 2018 $ 0.790 $ 3.16 $ 25,960 November 9, 2018 November 2, 2018 December 31, 2018 $ 0.810 $ 3.24 $ 26,949 February 12, 2019 February 4, 2019 The allocation of total quarterly cash distributions made to general and limited partners for the years ended December 31, 2018 , 2017 and 2016 is set forth in the table below. Distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below presents total cash distributions applicable to the period in which the distributions are earned (in thousands, except per unit amounts): Year Ended December 31, 2018 2017 2016 General partner's distributions: General partner's distributions $ 1,553 $ 1,408 $ 1,277 General partner's IDRs 24,224 17,389 11,160 Total general partner's distributions 25,777 18,797 12,437 Limited partners' distributions: Common 76,113 69,057 58,158 Subordinated — — 4,424 Total limited partners' distributions 76,113 69,057 62,582 Total cash distributions $ 101,890 $ 87,854 $ 75,019 Cash distributions per limited partner unit $ 3.120 $ 2.835 $ 2.575

Equity Based Compensation (Tabl

Equity Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2018
Share-based Compensation [Abstract]
Schedule of Share-based Compensation, Phantom Units Award Activity	A summary of our unit award activity for the years ended December 31, 2018 , 2017 and 2016 , is set forth below: Number of Phantom Units Weighted-Average Grant Price Non-vested December 31, 2015 145,072 $ 24.76 Granted 12,475 $ 26.05 Vested (69,094 ) $ 24.66 Forfeited (14,500 ) $ 22.65 Non-vested December 31, 2016 73,953 $ 25.49 Granted 10,090 $ 32.2 Vested (68,079 ) $ 24.6 Forfeited — $ — Non-vested December 31, 2017 15,964 $ 33.54 Granted 19,536 $ 28.57 Vested (21,818 ) $ 31.76 Non-vested December 31, 2018 13,682 $ 29.29

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Combined summarized financial information for our equity method investees is shown below (in thousands): Year Ended Year Ended December 31, 2018 December 31, 2017 Current assets $ 15,450 $ 12,671 Non-current assets $ 240,852 $ 244,329 Current liabilities $ 4,362 $ 1,798 Year Ended Year Ended Year Ended December 31, 2018 December 31, 2017 December 31, 2016 Revenues $ 35,050 $ 28,805 $ 2,217 Gross profit $ 17,690 $ 13,344 $ (2,048 ) Net Income/loss $ 15,701 $ 10,714 $ (3,641 )

Segment Data (Tables)

Segment Data (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following is a summary of business segment operating performance as measured by contribution margin for the periods indicated (in thousands): Year Ended December 31, 2018 2017 2016 Pipelines and Transportation Net revenues: Affiliate 138,418 $ 109,298 103,749 Third party 15,149 12,431 18,423 Total pipelines and transportation 153,567 121,729 122,172 Cost of materials and other 19,878 18,210 19,425 Operating expenses (excluding depreciation and amortization) 39,934 33,240 29,235 Segment contribution margin $ 93,755 $ 70,279 $ 73,512 Capital spending (1) $ 6,840 $ 14,262 $ 8,478 Wholesale Marketing and Terminalling Net revenues: Affiliate (2) 102,391 46,982 45,815 Third party 401,651 369,364 280,072 Total wholesale marketing and terminalling 504,042 416,346 325,887 Cost of materials and other 409,183 354,680 282,733 Operating expenses (excluding depreciation and amortization) 18,810 10,034 7,963 Segment contribution margin $ 76,049 $ 51,632 $ 35,191 Capital spending (1) $ 4,725 $ 4,141 $ 3,289 Consolidated Net revenues: Affiliate $ 240,809 $ 156,280 $ 149,564 Third party 416,800 381,795 298,495 Total Consolidated 657,609 538,075 448,059 Cost of materials and other 429,061 372,890 302,158 Operating expenses (excluding depreciation and amortization presented below) 58,744 43,274 37,198 Contribution margin 169,804 121,911 108,703 General and administrative expenses 17,166 11,840 10,256 Depreciation and amortization 25,990 21,914 20,813 Loss (gain) on asset disposals 891 (20 ) (16 ) Operating income $ 125,757 $ 88,177 $ 77,650 Capital spending (1) $ 11,565 $ 18,403 $ 11,767 (1) Capital spending excludes transaction costs capitalized in the amount of $0.4 million that relate to the Big Spring Logistic Assets Acquisition for the year ended December 31, 2018 . (2) Affiliate revenue for the wholesale marketing and terminalling segment is presented net of amortization expense pertaining to the Marketing Contract Intangible Acquisition. See Note 3 for additional information. The following table summarizes the total assets for each segment as of December 31, 2018 and 2017 (in thousands). Year Ended December 31, 2018 2017 Pipelines and transportation $ 387,333 $ 349,351 Wholesale marketing and terminalling 237,260 94,179 Total assets $ 624,593 $ 443,530

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value, Assets Measured on Recurring Basis	The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis at December 31, 2018 and 2017 was as follows: (in thousands): As of December 31, 2018 Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ — $ 186 $ — $ 186 Total assets — 186 — 186 Liabilities Commodity derivatives — (2 ) — (2 ) Net liabilities $ — $ 184 $ — $ 184 As of December 31, 2017 Level 1 Level 2 Level 3 Total Liabilities Commodity derivatives — (1,087 ) — (1,087 ) Net liabilities $ — $ (1,087 ) $ — $ (1,087 )

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value of our derivative instruments, as of December 31, 2018 and 2017 . The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including any cash deficit or collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below differ from the amounts presented in our accompanying consolidated balance sheets. During the years ended December 31, 2018 and 2017 , we did not elect hedge accounting treatment for these derivative positions. As a result, all changes in fair value are marked to market in the accompanying consolidated statements of income and comprehensive income. See Note 16 for further information regarding the fair value of derivative instruments. (in thousands) December 31, 2018 December 31, 2017 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives: Commodity derivatives (1) Other current assets $ 186 $ (2 ) $ — $ (1,087 ) Total gross fair value of derivatives 186 (2 ) — (1,087 ) Less: Counterparty netting and cash deficit (collateral) (2) (404 ) (2 ) — (290 ) Total net fair value of derivatives $ 590 $ — $ — $ (797 ) (1) As of December 31, 2018 and 2017 , we had open derivative contracts representing 82,000 barrels and 370,000 barrels, respectively, of refined petroleum products. (2) As of December 31, 2018 and 2017 , we had cash collateral of $0.4 million and $0.3 million
Derivative Instruments, Gain (Loss)	Recognized gains (losses) associated with our derivatives for the years ended December 31, 2018 and 2017 were as follows (in thousands): Year Ended December 31, Derivative Type Income Statement Location 2018 2017 2016 Commodity derivatives Cost of materials and other 3,325 (1,550 ) (2,122 )

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	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, 2018 2017 2016 State income taxes $ 534 (222 ) 121 Other items $ — — (40 ) Income tax expense (benefit) $ 534 $ (222 ) $ 81
Schedule of Components of Income Tax Expense (Benefit)	Income tax expense (benefit) is as follows (in thousands): Year Ended December 31, 2018 2017 2016 Current $ 382 $ (111 ) $ 254 Deferred $ 152 (111 ) (173 ) Total $ 534 $ (222 ) $ 81

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases	The following is an estimate of our future minimum lease payments for operating leases having remaining noncancelable terms in excess of one year as of December 31, 2018 (in thousands): 2019 $ 5,755 2020 5,659 2021 5,337 2022 5,031 2023 2,429 Thereafter 8 Total future minimum rentals $ 24,219

Selected Quarterly Financial _2

Selected Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Selected Quarterly Financial Information [Abstract]
Schedule of Quarterly Financial Data	Quarterly financial information for the years ended December 31, 2018 and 2017 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). For the Three Month Periods Ended March 31, 2018 June 30, 2018 September 30, 2018 December 31, 2018 Net revenues $ 167,921 $ 166,280 $ 164,110 $ 159,298 Operating income $ 27,277 $ 34,710 $ 32,624 $ 31,147 Net income $ 19,995 $ 25,582 $ 23,326 $ 21,280 Limited partners' interest in net income $ 14,365 $ 19,370 $ 16,690 $ 14,215 Net income per limited partner unit: Common (basic) $ 0.59 $ 0.79 $ 0.68 $ 0.58 Common (diluted) $ 0.59 $ 0.79 $ 0.68 $ 0.58 For the Three Month Periods Ended March 31, 2017 June 30, 2017 September 30, 2017 December 31, 2017 Net revenues $ 129,473 $ 126,769 $ 130,626 $ 151,207 Operating income $ 18,472 $ 23,371 $ 22,636 $ 23,698 Net income $ 14,595 $ 18,977 $ 16,923 $ 18,914 Limited partners' interest in net income $ 10,486 $ 14,425 $ 12,178 $ 13,891 Net income per limited partner unit: Common (basic) $ 0.43 $ 0.59 $ 0.50 $ 0.57 Common (diluted) $ 0.43 $ 0.59 $ 0.50 $ 0.57

General (Details)

General (Details) - Delek	12 Months Ended
	Dec. 31, 2018
Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	5 years
Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	10 years

Accounting Policies Segment Rep

Accounting Policies Segment Reporting and Accounts Receivable (Details)	12 Months Ended
	Dec. 31, 2018USD ($)segmentcustomer	Dec. 31, 2017USD ($)customer
Concentration Risk [Line Items]
Number of reportable segments | segment	2
Allowance for doubtful accounts | $	$ 0	$ 0
Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Number of customers | customer	2	1
Concentration risk, percentage	50.40%	22.00%

Accounting Policies Inventory (

Accounting Policies Inventory (Details) - Supplier Concentration Risk - Inventory purchased - Wholesale Marketing and Terminalling - vendor	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Concentration Risk [Line Items]
Number of vendors		2
Concentration risk, percentage	64.20%	11.60%	72.00%
Delek
Concentration Risk [Line Items]
Concentration risk, percentage		65.80%

Accounting Policies Property, P

Accounting Policies Property, Plant and Equipment (Details)	6 Months Ended
	Jun. 30, 2018
Minimum | Building and building improvements
Estimated useful life (years)	15 years
Minimum | Pipelines, tanks and terminals
Estimated useful life (years)	15 years
Minimum | Asset retirement obligation assets
Estimated useful life (years)	15 years
Minimum | Other equipment
Estimated useful life (years)	3 years
Maximum | Building and building improvements
Estimated useful life (years)	40 years
Maximum | Pipelines, tanks and terminals
Estimated useful life (years)	40 years
Maximum | Asset retirement obligation assets
Estimated useful life (years)	50 years
Maximum | Other equipment
Estimated useful life (years)	15 years

Accounting Policies Intangible

Accounting Policies Intangible Assets (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Supply contract
Acquired Finite-Lived Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months	11 years 6 months
Marketing contract
Acquired Finite-Lived Intangible Assets [Line Items]
Estimated useful life (years)	20 years

Accounting Policies Asset Retir

Accounting Policies Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 4,064	$ 3,772
Liabilities acquired	768	0
Accretion expense	359	292	$ 266
Ending balance	$ 5,191	$ 4,064	$ 3,772

Accounting Policies Deferred Fi

Accounting Policies Deferred Financing Costs (Details)	Dec. 31, 2018	May 23, 2017
Senior Notes | 2025 Notes
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	6.75%	6.75%

Accounting Policies Net Income

Accounting Policies Net Income per Limited Partner Unit (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
General partner's ownership interest	2.00%	2.00%	2.00%
Distributions from equity method investments	$ 1,162	$ 753	$ 0

Acquisitions Narrative (Details

Acquisitions Narrative (Details) $ in Thousands	Mar. 01, 2018USD ($)storage_tankunderground_saltwell	Sep. 15, 2017USD ($)mi	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Business Acquisition [Line Items]
Intangible assets			$ 154,038	$ 15,917
Property, plant and equipment			312,562	$ 255,068
Big Spring Logistic Assets
Business Acquisition [Line Items]
Purchase price of asst acquisition	$ 170,800
Number of storage tanks | storage_tank	75
Number of underground saltwells | underground_saltwell	4
Excess of cash paid over carrying value	$ 98,800
Carrying value of assets acquired	72,000
Assumed asset retirement obligation	800
Capitalized acquisition costs			$ 400
Intangible assets	$ 144,200
Amortization period	20 years
Big Spring Pipeline
Business Acquisition [Line Items]
Purchase price of asst acquisition		$ 9,000
Intangible assets		$ 2,600
Length of pipeline | mi		40
Property, plant and equipment		$ 6,400

Related Party Transactions Comm

Related Party Transactions Commercial Agreements (Details)		Mar. 01, 2018USD ($)bbl / pure$ / bbl	Mar. 31, 2015USD ($)$ / bbl	Feb. 28, 2014USD ($)bbl / pure$ / bbl	Oct. 31, 2013bbl / pure$ / bbl	Jul. 31, 2013USD ($)bbl / pure$ / bbl	Nov. 30, 2012USD ($)bbl / pure$ / bbl	Dec. 31, 2018$ / bbl
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Crude Oil Pipeline
Related Party Transaction [Line Items]
Term of agreement (years)								10 years
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Crude Oil Pipeline | Minimum
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)								0.05
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Crude Oil Pipeline | Maximum
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)								0.66
Big Spring Asphalt Services Agreement
Related Party Transaction [Line Items]
Term of agreement (years)								10 years
Big Spring Asphalt Services Agreement | Storage
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)								8.30
Big Spring Marketing Agreement
Related Party Transaction [Line Items]
Term of agreement (years)								10 years
Big Spring Marketing Agreement | Crude Oil Pipeline | Minimum
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)								0.50
Big Spring Marketing Agreement | Crude Oil Pipeline | Maximum
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)								0.71
Delek | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)								5 years
Delek | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)								10 years
Delek | Lion Pipeline System and SALA Gathering System | Crude Oil Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)	[1]						46,000
Throughput commitment tariff rate (dollars per barrel)	[2]						0.99
Delek | Lion Pipeline System and SALA Gathering System | Crude Oil Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)							5 years
Delek | Lion Pipeline System and SALA Gathering System | Crude Oil Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]						15 years
Delek | Lion Pipeline System and SALA Gathering System | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)							40,000
Throughput commitment tariff rate (dollars per barrel)							0.12
Delek | Lion Pipeline System and SALA Gathering System | Refined Product Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)							5 years
Delek | Lion Pipeline System and SALA Gathering System | Refined Product Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]						15 years
Delek | Lion Pipeline System and SALA Gathering System | SALA Gathering System
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)							14,000
Throughput commitment tariff rate (dollars per barrel)	[2]						2.66
Delek | Lion Pipeline System and SALA Gathering System | SALA Gathering System | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)							5 years
Delek | Lion Pipeline System and SALA Gathering System | SALA Gathering System | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]						15 years
Delek | East Texas Crude Logistics System
Related Party Transaction [Line Items]
Throughput volume subject to additional fee (bpd)							50,000
Throughput commitment rate, additional for excess barrels (dollars per barrel)							0.700
Delek | East Texas Crude Logistics System | Crude Oil Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)							35,000
Throughput commitment tariff rate (dollars per barrel)	[4]						0.47
Delek | East Texas Crude Logistics System | Crude Oil Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)							5 years
Delek | East Texas Crude Logistics System | Crude Oil Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]						15 years
Delek | East Texas Crude Logistics System | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $							$ 291,220
Delek | East Texas Crude Logistics System | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)							5 years
Delek | East Texas Crude Logistics System | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]						15 years
Delek | East Texas Marketing
Related Party Transaction [Line Items]
Term of agreement (years)	[5]						15 years
Minimum throughput commitment (bpd)							50,000
Throughput commitment tariff rate (dollars per barrel)	[5]						0.8000
Throughput volume subject to additional fee (bpd)							50,000
Throughput commitment rate, additional for excess barrels (dollars per barrel)							0.750
Delek | Big Sandy Terminal | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)	[6]						5,000
Throughput commitment tariff rate (dollars per barrel)	[6]						0.58
Delek | Big Sandy Terminal | Refined Product Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	[6]						5 years
Delek | Big Sandy Terminal | Refined Product Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3],[6]						15 years
Delek | Big Sandy Terminal | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $	[6]						$ 58,192
Delek | Big Sandy Terminal | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	[6]						5 years
Delek | Big Sandy Terminal | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3],[6]						15 years
Delek | Big Sandy Terminal | Big Sandy Terminal
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)	[6]						5,000
Throughput commitment tariff rate (dollars per barrel)	[6]						0.58
Delek | Big Sandy Terminal | Big Sandy Terminal | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	[6]						5 years
Delek | Big Sandy Terminal | Big Sandy Terminal | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3],[6]						15 years
Delek | Tyler Terminal Throughput and Tankage
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)						50,000
Throughput commitment tariff rate (dollars per barrel)						0.37
Delek | Tyler Terminal Throughput and Tankage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)						11 years
Delek | Tyler Terminal Throughput and Tankage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]					16 years
Delek | Tyler Terminal Throughput and Tankage | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $						$ 871,336
Delek | Tyler Terminal Throughput and Tankage | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)						11 years
Delek | Tyler Terminal Throughput and Tankage | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]					16 years
Delek | Memphis Pipeline
Related Party Transaction [Line Items]
Term of agreement (years)	[5]				5 years
Minimum throughput commitment (bpd)					10,959
Throughput commitment tariff rate (dollars per barrel)	[5]				1.41
Delek | El Dorado Throughput and Tankage | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)	[7]			11,000
Throughput commitment tariff rate (dollars per barrel)	[7]			0.53
Delek | El Dorado Throughput and Tankage | Refined Product Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	[7]			10 years
Delek | El Dorado Throughput and Tankage | Refined Product Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[7]			16 years
Delek | El Dorado Throughput and Tankage | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $	[7]			$ 1,363,985
Delek | El Dorado Throughput and Tankage | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)	[7]			10 years
Delek | El Dorado Throughput and Tankage | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[7]			16 years
Delek | El Dorado Assets
Related Party Transaction [Line Items]
Minimum throughput fee | $			$ 1,500,000
Delek | El Dorado Assets | Light Crude Oil
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	[8]		1.05
Delek | El Dorado Assets | Light Crude Oil | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)			9 years
Delek | El Dorado Assets | Light Crude Oil | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]		15 years
Delek | El Dorado Assets | Heavy Crude Oil
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	[8]		2.36
Delek | El Dorado Assets | Heavy Crude Oil | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)			9 years
Delek | El Dorado Assets | Heavy Crude Oil | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]		15 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)		104,300
Throughput commitment tariff rate (dollars per barrel)		0.05
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Refined Product Pipeline | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Refined Product Pipeline | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $		$ 1,374,630
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Rail Offloading
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)		4,500
Throughput commitment tariff rate (dollars per barrel)		0.40
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Rail Offloading | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Rail Offloading | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Dedicated Terminalling Services
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)		29,250
Throughput commitment tariff rate (dollars per barrel)		0.66
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Dedicated Terminalling Services | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Delek | Big Spring Pipeline, Storage And Throughput Facilities Agreement | Dedicated Terminalling Services | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Delek | Big Spring Asphalt Services Agreement | Storage
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $		$ 456,490
Delek | Big Spring Asphalt Services Agreement | Storage | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Delek | Big Spring Asphalt Services Agreement | Storage | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Delek | Big Spring Asphalt Services Agreement | Dedicated Asphalt Terminalling
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)		8.30
Delek | Big Spring Asphalt Services Agreement | Dedicated Asphalt Terminalling | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Minimum throughput commitment (bpd)		1,020
Delek | Big Spring Asphalt Services Agreement | Dedicated Asphalt Terminalling | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Minimum throughput commitment (bpd)		2,380
Delek | Big Spring Marketing Agreement | Dedicated Marketing and Selling
Related Party Transaction [Line Items]
Minimum throughput commitment (bpd)		65,000
Delek | Big Spring Marketing Agreement | Dedicated Marketing and Selling | Minimum
Related Party Transaction [Line Items]
Term of agreement (years)		10 years
Throughput commitment tariff rate (dollars per barrel)		0.50
Delek | Big Spring Marketing Agreement | Dedicated Marketing and Selling | Maximum
Related Party Transaction [Line Items]
Term of agreement (years)	[3]	15 years
Throughput commitment tariff rate (dollars per barrel)		0.71
[1]	Excludes volumes gathered on the SALA Gathering System.
[2]	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.
[3]	Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof.
[4]	For any volumes in excess of 50,000 bpd, the throughput fee will be $0.700
[5]	For any volumes in excess of 50,000 bpd, the throughput fee will be $0.750 /bbl. Following the primary term, the marketing agreement automatically renews for successive one-year term, unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. The initial primary term for the marketing agreement has been extended through 2027.
[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 Holdings 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 November 2012.
[7]	The current term of the agreement was extended through March 31, 2024 in connection with the amendment and restatement of the DKL Credit Facility (as defined in Note 11
[8]	The throughput agreement provides for a minimum throughput fee of $1.5 million

Related Party Transactions Big

Related Party Transactions Big Spring Agreements (Details)	12 Months Ended
	Dec. 31, 2018$ / bbl
Big Spring Asphalt Services Agreement
Related Party Transaction [Line Items]
Term of agreement (years)	10 years
One-time option to extend, maximum number of years	5 years
Big Spring Marketing Agreement
Related Party Transaction [Line Items]
Term of agreement (years)	10 years
One-time option to extend, maximum number of years	5 years
Crude Oil Pipeline | Big Spring Pipeline, Storage And Throughput Facilities Agreement
Related Party Transaction [Line Items]
Term of agreement (years)	10 years
One-time option to extend, maximum number of years	5 years
Storage | Big Spring Asphalt Services Agreement
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	8.30
Minimum | Crude Oil Pipeline | Big Spring Pipeline, Storage And Throughput Facilities Agreement
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	0.05
Minimum | Crude Oil Pipeline | Big Spring Marketing Agreement
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	0.50
Maximum | Crude Oil Pipeline | Big Spring Pipeline, Storage And Throughput Facilities Agreement
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	0.66
Maximum | Crude Oil Pipeline | Big Spring Marketing Agreement
Related Party Transaction [Line Items]
Throughput commitment tariff rate (dollars per barrel)	0.71

Related Party Transactions Othe

Related Party Transactions Other Agreements (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating and maintenance expenses | Partnership Agreement | General Partner
Related Party Transaction [Line Items]
Payment for management fee	$ 21.1	$ 18.8	$ 15.7

Related Party Transactions Omni

Related Party Transactions Omnibus Agreement (Details) - USD ($) $ in Thousands	Mar. 01, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Reimbursement of capital expenditures by Delek Holdings		$ 5,005	$ 4,262	$ 1,880
Omnibus Agreement | Delek
Related Party Transaction [Line Items]
Obligation to pay annual fee	$ 3,900
Omnibus Agreement | Delek US | Delek
Related Party Transaction [Line Items]
Recovery of direct costs		9,800
Omnibus Agreement | Operating and maintenance expenses | Delek US | Delek
Related Party Transaction [Line Items]
Recovery of direct costs		8,200	300	1,200
Other Noncurrent Liabilities | Omnibus Agreement | Delek US | Delek
Related Party Transaction [Line Items]
Reimbursement of capital expenditures by Delek Holdings		5,000	$ 4,300	$ 1,900
Partnership Agreement | Operating and maintenance expenses | General Partner
Related Party Transaction [Line Items]
Receivable from related parties		$ 1,600

Related Party Transactions Summ

Related Party Transactions Summary of Transactions (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Revenues	[1]	$ 240,809	$ 156,280	$ 149,564
Delek
Related Party Transaction [Line Items]
Revenues		240,809	156,280	149,564
General and administrative expenses		8,250	7,492	6,254
Purchases from Affiliates | Delek
Related Party Transaction [Line Items]
Expenses		349,089	54,982	32,514
Operating and maintenance expenses | Delek
Related Party Transaction [Line Items]
Expenses		36,182	$ 29,483	$ 27,668
DPG Management Agreement, Operating Service And Construction Fee Paid To Partnership | Delek
Related Party Transaction [Line Items]
Expenses		$ 4,800
[1]	See Note 4 for a description of our material affiliate revenue transactions.

Related Party Transactions Quar

Related Party Transactions Quarterly Cash Distributions Paid (Details) - USD ($) $ in Thousands	Feb. 12, 2019	Jan. 24, 2019	Nov. 09, 2018	Aug. 13, 2018	May 15, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	Feb. 14, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Cash distributions paid			$ 25,960	$ 24,984	$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,024	$ 20,537	$ 101,900	$ 87,900	$ 75,000
Subsequent Event
Related Party Transaction [Line Items]
Cash distributions paid	$ 26,949	$ 26,900
Delek
Related Party Transaction [Line Items]
Cash distributions paid											$ 70,100	$ 60,100	$ 47,000
Delek | Subsequent Event
Related Party Transaction [Line Items]
Cash distributions declared	$ 19,600

Revenues (Details)

Revenues (Details) - USD ($) $ in Thousands

3 Months Ended

12 Months Ended

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Disaggregation of Revenue [Line Items]

Net revenues

$ 159,298

$ 164,110

$ 166,280

$ 167,921

$ 151,207

$ 130,626

$ 126,769

$ 129,473

$ 657,609

$ 538,075

$ 448,059

Amortization of customer contract intangible assets

6,009

0

0

Service Revenue - Third Party

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

16,019

Service Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

[1]

147,050

Product Revenue - Third Party

Disaggregation of Revenue [Line Items]

Net revenues

400,781

Product Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

35,252

Lease Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

58,507

Pipelines and Transportation

Disaggregation of Revenue [Line Items]

Net revenues

153,567

121,729

122,172

Pipelines and Transportation | Service Revenue - Third Party

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

15,149

Pipelines and Transportation | Service Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

[1]

93,300

Pipelines and Transportation | Product Revenue - Third Party

Disaggregation of Revenue [Line Items]

Net revenues

0

Pipelines and Transportation | Product Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

0

Pipelines and Transportation | Lease Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

45,118

Wholesale Marketing and Terminalling

Disaggregation of Revenue [Line Items]

Net revenues

504,042

$ 416,346

$ 325,887

Wholesale Marketing and Terminalling | Service Revenue - Third Party

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

870

Wholesale Marketing and Terminalling | Service Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Revenue from contracts with customers

[1]

53,750

Wholesale Marketing and Terminalling | Product Revenue - Third Party

Disaggregation of Revenue [Line Items]

Net revenues

400,781

Wholesale Marketing and Terminalling | Product Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

35,252

Wholesale Marketing and Terminalling | Lease Revenue - Affiliate

Disaggregation of Revenue [Line Items]

Net revenues

$ 13,389

Sales Revenue | Delek | Customer Concentration Risk

Disaggregation of Revenue [Line Items]

Concentration risk, percentage

36.60%

28.90%

32.80%

Sales Revenue | Sunoco | Customer Concentration Risk

Disaggregation of Revenue [Line Items]

Concentration risk, percentage

15.90%

9.00%

10.50%

[1]

Net of $6.0 million

Revenues Revenues Remaining Per

Revenues Revenues Remaining Performance Obligation Expected Timing of Satisfaction - Period (Details) $ in Thousands	Dec. 31, 2018USD ($)
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 1,144,687
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 168,315
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 167,965
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 167,620
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 166,587
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 474,200
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction

Net Income Per Unit Narrative (

Net Income Per Unit Narrative (Details) - shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Feb. 25, 2016
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
General partner's ownership interest	2.00%	2.00%	2.00%
Subordinated- Delek
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Limited Partners' capital account, units outstanding (in units)				11,999,258

Net Income Per Unit Calculation

Net Income Per Unit Calculation of Net Income Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Feb. 25, 2016
Net income per unit [Line Items]
Net income attributable to partners										$ 90,182	$ 69,409	$ 62,804
(Distributions) earnings excess										$ (11,708)	$ (18,445)	$ (12,215)
Footnote [Abstract]
General partner's ownership interest										2.00%	2.00%	2.00%
Common units excluded from computation of earnings per share (in units)										1,776	0
Maximum | First target distribution
Footnote [Abstract]
Distribution payment targets (in usd per unit)										$ 0.43125
General Partner
Net income per unit [Line Items]
Total earnings										$ 25,543	$ 18,429	$ 12,193
Common Units
Weighted average limited partner units outstanding:
Common units - (basic) (in units)	[1]									24,390,286	24,348,063	22,490,264
Common units - (diluted) (in units)	[1]									24,396,881	24,376,972	22,558,717
Net income per limited partner unit:
Common units - (basic) (in usd per unit)		$ 0.58	$ 0.68	$ 0.79	$ 0.59	$ 0.57	$ 0.50	$ 0.59	$ 0.43	$ 2.65	$ 2.09	$ 2.08
Common units - (diluted) (in usd per unit)		$ 0.58	$ 0.68	$ 0.79	$ 0.59	$ 0.57	$ 0.50	$ 0.59	$ 0.43	$ 2.65	$ 2.09	$ 2.07
Footnote [Abstract]
Common units excluded from computation of earnings per share (in units)												4,240
Subordinated- Delek
Weighted average limited partner units outstanding:
Subordinated units - Delek Holdings (basic and diluted) (in units)	[1]									0	0	1,803,167
Net income per limited partner unit:
Subordinated units - Delek Holdings (basic and diluted) (in usd per unit)										$ 0	$ 0	$ 2.19
Footnote [Abstract]
Limited Partners' capital account, units outstanding (in units)													11,999,258
General Partner
Net income per unit [Line Items]
Net income attributable to partners										$ 25,543	$ 18,429	$ 12,193
General partner's distribution	[2]									25,777	18,797	12,437
(Distributions) earnings excess										(234)	(368)	(244)
Limited Partner
Net income per unit [Line Items]
Limited partners' distribution										76,113	69,057	62,582
Limited Partner | Common Units
Net income per unit [Line Items]
Limited partners' distribution										76,113	69,057	58,158
(Distributions) earnings excess										(11,474)	(18,077)	(11,489)
Total earnings										$ 64,639	$ 50,980	$ 46,669
Weighted average limited partner units outstanding:
Common units - (basic) (in units)	[3]									24,390,286	24,348,063	22,490,264
Common units - (diluted) (in units)	[3]									24,396,881	24,376,972	22,558,717
Net income per limited partner unit:
Common units - (basic) (in usd per unit)										$ 2.65	$ 2.09	$ 2.08
Common units - (diluted) (in usd per unit)	[4]									$ 2.65	$ 2.09	$ 2.07
Limited Partner | Subordinated Units
Net income per unit [Line Items]
Limited partners' distribution										$ 0	$ 0	$ 4,424
(Distributions) earnings excess										0	0	(482)
Total earnings										$ 0	$ 0	$ 3,942
Weighted average limited partner units outstanding:
Subordinated units - Delek Holdings (basic and diluted) (in units)	[3],[5]									0	0	1,803,167
Net income per limited partner unit:
Subordinated units - Delek Holdings (basic and diluted) (in usd per unit)										$ 0	$ 0	$ 2.19
Limited Partner | Subordinated- Delek
Net income per unit [Line Items]
Net income attributable to partners												$ 3,942
[1]	We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflect the conversion of the subordinated units to common units on February 25, 2016. See Notes 6 and 12
[2]	General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs.
[3]	We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflects the conversion of the subordinated units to common units on February 25, 2016.
[4]	Outstanding common unit equivalents totaling 1,776 and 4,240 were excluded from the diluted earnings per unit calculation for the years ended December 31, 2018 and 2016 , respectively, as these common unit equivalents did not have a dilutive effect under the treasury stock method. There were no outstanding common unit equivalents excluded from the diluted earnings per unit calculation during the year ended December 31, 2017
[5]	On February 25, 2016, all of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. Distributions and the Partnership's net income were allocated to the subordinated units through February 24, 2016.

Inventory Narrative (Details)

Inventory Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Inventory [Line Items]
Inventory	$ 5,491,000	$ 20,855,000
Purchases from Affiliates
Inventory [Line Items]
Inventory Write-down	$ 200,000	$ 0	$ 0

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 452,746	$ 367,179
Less: accumulated depreciation	(140,184)	(112,111)
Property, plant and equipment, net	312,562	255,068
Depreciation expense	25,901	20,851
Pipelines and Transportation
Property, Plant and Equipment [Line Items]
Property, plant and equipment	361,702	300,134
Less: accumulated depreciation	(106,971)	(84,435)
Property, plant and equipment, net	254,731	215,699
Depreciation expense	21,115	17,268
Wholesale Marketing and Terminalling
Property, Plant and Equipment [Line Items]
Property, plant and equipment	91,044	67,045
Less: accumulated depreciation	(33,213)	(27,676)
Property, plant and equipment, net	57,831	39,369
Depreciation expense	4,786	3,583
Land
Property, Plant and Equipment [Line Items]
Property, plant and equipment	4,458	4,440
Building and building improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	3,695	2,804
Pipelines, tanks and terminals
Property, Plant and Equipment [Line Items]
Property, plant and equipment	410,154	314,251
Asset retirement obligation assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,073	2,073
Other equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	15,838	14,650
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 16,528	$ 28,961

Goodwill Narrative (Details)

Goodwill Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Goodwill [Line Items]
Goodwill, impairment loss	$ 0	$ 0	$ 0
Goodwill	12,203,000	12,203,000
Wholesale Marketing and Terminalling
Goodwill [Line Items]
Goodwill	7,500,000	7,500,000	7,500,000
Pipelines and Transportation
Goodwill [Line Items]
Goodwill	$ 4,700,000	$ 4,700,000	$ 4,700,000

Other Intangible Assets (Detail

Other Intangible Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2019
Other Intangible Assets [Line Items]
Accumulated amortization	$ (18,236)	$ (12,138)
Intangible assets, gross	172,274	28,055
Intangible assets, net	154,038	15,917
Rights-of-way assets
Other Intangible Assets [Line Items]
Rights-of-way assets	$ 15,828	$ 15,828
Supply contract
Other Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months	11 years 6 months
Intangible assets, gross	$ 12,227	$ 12,227
Accumulated amortization	(12,227)	(12,138)
Intangible assets, net	0	89
Amortization expense	$ 6,100	$ 1,100	$ 1,100
Marketing contract
Other Intangible Assets [Line Items]
Estimated useful life (years)	20 years
Intangible assets, gross	$ 144,219
Accumulated amortization	(6,009)
Intangible assets, net	$ 138,210
Scenario, Forecast | Supply contract
Other Intangible Assets [Line Items]
Estimated future amortization expense				$ 7,200

Long-Term Obligations DKL Credi

Long-Term Obligations DKL Credit Facility (Details) - Revolving Credit Facility - Fifth Third Bank - Line of Credit - USD ($)	12 Months Ended
	Dec. 31, 2018	Sep. 28, 2018	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Weighted average interest rate	5.40%
Second Amended and Restated Credit Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity				$ 700,000,000
Holdings Note outstanding amount	$ 102,000,000
Unused capacity, commitment fee percentage	0.50%
Line of credit facility, amount outstanding	$ 456,700,000		$ 456,700,000
Available borrowing capacity	$ 393,300,000
DKL Revolver [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 850,000,000
Accordion feature, increase limit				100,000,000
Maximum borrowing capacity under accordion feature		$ 1,000,000,000
Line of credit facility, amount outstanding				$ 179,900,000

Long-Term Obligations 6.750% Se

Long-Term Obligations 6.750% Senior Notes Due 2025 (Details) - Senior Notes - 2025 Notes - USD ($)	May 23, 2017	Dec. 31, 2018	Jun. 30, 2018
Debt Instrument [Line Items]
Debt instrument, face amount	$ 250,000,000
Debt instrument, interest rate, stated percentage	6.75%	6.75%
Debt instrument, redemption price, percentage of principal amount redeemed	35.00%
Line of credit facility, amount outstanding		$ 250,000,000	$ 250,000,000
Deferred financing costs		(4,800,000)
Debt discount		$ (1,500,000)
Prior to May 15, 2020
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	106.75%
Twelve-Month Period Beginning on May 15, 2020
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	105.063%
Twelve-Month Period Beginning on May 15, 2021
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	103.375%
Twelve-Month Period Beginning on May 15, 2022
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	101.688%
Twelve-Month Period Beginning on May 15, 2023
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	100.00%
Debt Instrument, Redemption, Change Of Control
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed	101.00%

Long-Term Obligations Maturitie

Long-Term Obligations Maturities of Long-term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Jun. 30, 2018
DKL Credit Facility | Revolving Credit Facility | Fifth Third Bank | Line of Credit
Debt Instrument [Line Items]
2,019		$ 0
2,020		0
2,021		0
2,022		0
2,023		456,700
Thereafter		0
Total	$ 456,700	456,700
2025 Notes | Senior Notes
Debt Instrument [Line Items]
2,019		0
2,020		0
2,021		0
2,022		0
2,023		0
Thereafter		250,000
Total	$ 250,000	$ 250,000

Equity (Details)

Equity (Details) - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Feb. 25, 2016
Limited Partners' Capital Account [Line Items]
General partner's ownership interest	2.00%	2.00%	2.00%
Maximum percentage increase of cash distributions from operating surplus	48.00%
Excess per unit of cash distributions (in usd per unit)	$ 0.43125
Common - Public
Limited Partners' Capital Account [Line Items]
Limited Partners' capital account, units outstanding (in units)	9,109,807
Common - Delek Holdings
Limited Partners' Capital Account [Line Items]
Limited Partners' capital account, units outstanding (in units)	15,294,046
Subordinated- Delek
Limited Partners' Capital Account [Line Items]
Limited Partners' capital account, units outstanding (in units)				11,999,258
Delek US
Limited Partners' Capital Account [Line Items]
Delek's ownership interest in General Partner	94.60%
Other Affiliates
Limited Partners' Capital Account [Line Items]
Delek's ownership interest in General Partner	5.40%
Delek US Holdings, Inc.
Limited Partners' Capital Account [Line Items]
Delek's Limited Partner interest	61.40%

Equity Units Rollforward (Detai

Equity Units Rollforward (Details) - shares		6 Months Ended		12 Months Ended
		Jun. 30, 2018		Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)		24,880,237		24,880,237	24,825,109		24,772,234
GP units issued to maintain 2% interest (in units)				434	1,102		1,057
General partner's ownership interest				2.00%	2.00%		2.00%
Unit-based compensation awards (in units)		21,220	[1]		54,026	[1]	51,818
Delek Holdings unit repurchases from public (in units)					0		0
Subordinated unit conversion (in units)							0
Ending balance (in units)				24,901,891	24,880,237		24,825,109
Units withheld for taxes (in units)				598	14,053		17,276
General Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)		497,604		497,604	496,502		495,445
GP units issued to maintain 2% interest (in units)				434	1,102		1,057
Unit-based compensation awards (in units)	[1]			0	0		0
Delek Holdings unit repurchases from public (in units)					0		0
Subordinated unit conversion (in units)							0
Ending balance (in units)				498,038	497,604		496,502
Common - Public | Limited Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)		9,088,587		9,088,587	9,263,415		9,478,273
GP units issued to maintain 2% interest (in units)				0	0		0
Unit-based compensation awards (in units)	[1]			21,220	54,026		51,818
Delek Holdings unit repurchases from public (in units)					(228,854)		(266,676)
Subordinated unit conversion (in units)							0
Ending balance (in units)				9,109,807	9,088,587		9,263,415
Common - Delek Holdings | Limited Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)		15,294,046		15,294,046	15,065,192		2,799,258
GP units issued to maintain 2% interest (in units)				0	0		0
Unit-based compensation awards (in units)	[1]			0	0		0
Delek Holdings unit repurchases from public (in units)					228,854		266,676
Subordinated unit conversion (in units)							11,999,258
Ending balance (in units)				15,294,046	15,294,046		15,065,192
Subordinated | Limited Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)		0		0	0		11,999,258
GP units issued to maintain 2% interest (in units)				0	0		0
Unit-based compensation awards (in units)	[1]			0	0		0
Delek Holdings unit repurchases from public (in units)					0		0
Subordinated unit conversion (in units)							(11,999,258)
Ending balance (in units)				0	0		0
[1]	Unit-based compensation awards are presented net of 598 , 14,053 and 17,276 units withheld for taxes as of December 31, 2018 , 2017 and 2016

Equity Net income applicable to

Equity Net income applicable to partners (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Equity [Abstract]
Net income attributable to partners	$ 90,182	$ 69,409	$ 62,804
General partner's IDRs	(24,224)	(17,389)	(11,160)
Net income available to partners	$ 65,958	$ 52,020	$ 51,644
General partner's ownership interest	2.00%	2.00%	2.00%
General partner's allocated interest in net income	$ 1,319	$ 1,040	$ 1,033
Total general partner's interest in net income	$ 25,543	$ 18,429	$ 12,193

Equity Cash distributions (Deta

Equity Cash distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Feb. 12, 2019	Jan. 24, 2019	Nov. 09, 2018	Aug. 13, 2018	May 15, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	Feb. 14, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Distribution Made to Limited Partner [Line Items]
Total Quarterly Distribution Per Limited Partner Unit			$ 0.790	$ 0.770	$ 0.750	$ 0.725	$ 0.715	$ 0.705	$ 0.690	$ 0.680
Total Quarterly Distribution Per Limited Partner Unit, Annualized			$ 3.16	$ 3.08	$ 3	$ 2.90	$ 2.86	$ 2.82	$ 2.76	$ 2.72
Total Cash Distribution, including general partner interest and IDRs (in thousands)			$ 25,960	$ 24,984	$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,024	$ 20,537	$ 101,900	$ 87,900	$ 75,000
Less: General partner's IDRs											24,224	17,389	11,160
Total cash distributions											$ 101,890	$ 87,854	$ 75,019
Cash distributions per limited partner unit (in usd per unit)											$ 3.120	$ 2.835	$ 2.575
General Partner
Distribution Made to Limited Partner [Line Items]
General partner's distributions											$ 1,553	$ 1,408	$ 1,277
Less: General partner's IDRs											24,224	17,389	11,160
Total general partner's distributions											25,777	18,797	12,437
Limited Partner
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution											76,113	69,057	62,582
Limited Partner | Common Units
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution											76,113	69,057	58,158
Limited Partner | Subordinated
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution											$ 0	$ 0	$ 4,424
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Total Quarterly Distribution Per Limited Partner Unit	$ 0.810
Total Quarterly Distribution Per Limited Partner Unit, Annualized	$ 3.24
Total Cash Distribution, including general partner interest and IDRs (in thousands)	$ 26,949	$ 26,900

Equity Based Compensation Narra

Equity Based Compensation Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Number of units authorized	612,207
Total fair value of vested units	$ (0.7)	$ (1.7)	$ (1.7)
Unrecognized compensation costs	$ 0.3
Unrecognized compensation costs, weighted-average period for recognition	4 months 24 days
Minimum
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Awards requisite service period (years)	1 year
Maximum
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Awards requisite service period (years)	5 years
General and administrative expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Unit-based compensation expense	$ 0.7	$ 0.7	$ 0.6

Equity Based Compensation Unit

Equity Based Compensation Unit Award Activity Summary (Details) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Number of Phantom Units
Non-vested (units)	15,964	15,964	73,953	145,072
Granted (units)		19,536	10,090	12,475
Vested (units)		(21,818)	(68,079)	(69,094)
Forfeited (units)	(14,500)		0
Non-vested (units)		13,682	15,964	73,953
Weighted-Average Grant Price
Non-vested, weighted-average grant price, beginning of year (usd per unit)	$ 33.54	$ 33.54	$ 25.49	$ 24.76
Granted, weighted-average grant price (usd per unit)		28.57	32.2	26.05
Vested, weighted average grant price (usd per unit)		31.76	24.6	24.66
Forfeited, weighted average grant price (usd per unit)	$ 22.65		0
Non-vested, weighted-average grant price, end of year (usd per unit)		$ 29.29	$ 33.54	$ 25.49

Equity Method Investments Narra

Equity Method Investments Narrative (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)joint_venture	Dec. 31, 2017USD ($)
Schedule of Equity Method Investments [Line Items]
Number of joint ventures | joint_venture	2
Equity method investments | $	$ 104,770	$ 106,465
CP LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	50.00%
Rangeland Rio
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	33.00%

Equity Method Investments Summa

Equity Method Investments Summarized Financial Information (Details) - Joint Ventures - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Current assets	$ 15,450	$ 12,671
Non-current assets	240,852	244,329
Current liabilities	4,362	1,798
Revenues	35,050	28,805	$ 2,217
Gross profit	17,690	13,344	(2,048)
Net Income/loss	$ 15,701	$ 10,714	$ (3,641)

Segment Data Narrative (Details

Segment Data Narrative (Details)	12 Months Ended
	Dec. 31, 2018segment
Segment Reporting [Abstract]
Number of reportable segments	2

Segment Data (Details)

Segment Data (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Affiliate	[1]									$ 240,809	$ 156,280	$ 149,564
Third party										416,800	381,795	298,495
Net revenues		$ 159,298	$ 164,110	$ 166,280	$ 167,921	$ 151,207	$ 130,626	$ 126,769	$ 129,473	657,609	538,075	448,059
Cost of materials and other										429,061	372,890	302,158
Operating expenses (excluding depreciation and amortization)										58,744	43,274	37,198
Segment contribution margin										169,804	121,911	108,703
General and administrative expenses										17,166	11,840	10,256
Depreciation and amortization										25,990	21,914	20,813
Loss (gain) on asset disposals										891	(20)	(16)
Operating income		31,147	$ 32,624	$ 34,710	$ 27,277	23,698	$ 22,636	$ 23,371	$ 18,472	125,757	88,177	77,650
Capital spending	[2]									11,565	18,403	11,767
Total assets		624,593				443,530				624,593	443,530
Pipelines and Transportation
Segment Reporting Information [Line Items]
Affiliate										138,418	109,298	103,749
Third party										15,149	12,431	18,423
Net revenues										153,567	121,729	122,172
Cost of materials and other										19,878	18,210	19,425
Operating expenses (excluding depreciation and amortization)										39,934	33,240	29,235
Segment contribution margin										93,755	70,279	73,512
Capital spending	[2]										14,262	8,478
Total assets		387,333				349,351				387,333	349,351
Wholesale Marketing and Terminalling
Segment Reporting Information [Line Items]
Affiliate	[3]									102,391	46,982	45,815
Third party										401,651	369,364	280,072
Net revenues										504,042	416,346	325,887
Cost of materials and other										409,183	354,680	282,733
Operating expenses (excluding depreciation and amortization)										18,810	10,034	7,963
Segment contribution margin										76,049	51,632	35,191
Capital spending	[2]									6,840	4,141	$ 3,289
Total assets		237,260				$ 94,179				237,260	$ 94,179
Big Spring Logistic Assets
Segment Reporting Information [Line Items]
Capitalized acquisition costs		$ 400								$ 400
[1]	See Note 4 for a description of our material affiliate revenue transactions.
[2]	Capital spending excludes transaction costs capitalized in the amount of $0.4 million that relate to the Big Spring Logistic Assets Acquisition for the year ended December 31, 2018
[3]	Affiliate revenue for the wholesale marketing and terminalling segment is presented net of amortization expense pertaining to the Marketing Contract Intangible Acquisition. See Note 3

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral	$ 400	$ 300
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	186
Net liabilities	184	(1,087)
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Net liabilities	0	0
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	186
Net liabilities	184	(1,087)
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Net liabilities	0	0
Fair Value, Measurements, Recurring | Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	186
Derivative liability	(2)	(1,087)
Fair Value, Measurements, Recurring | Commodity derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liability	0	0
Fair Value, Measurements, Recurring | Commodity derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	186
Derivative liability	(2)	(1,087)
Fair Value, Measurements, Recurring | Commodity derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liability	$ 0	$ 0

Derivative Instruments Narrativ

Derivative Instruments Narrative (Details)	12 Months Ended
	Dec. 31, 2018
Fuel | Forward Contracts
Derivative [Line Items]
Fulfillment term of derivative contract	90 days

Derivative Instruments (Details

Derivative Instruments (Details) $ in Thousands		Dec. 31, 2018USD ($)bbl	Dec. 31, 2017USD ($)bbl
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral		$ 400	$ 300
Derivatives not designated as hedging instrument
Derivative Instruments, Gain (Loss) [Line Items]
Assets		186	0
Less: Counterparty netting and cash deficit (collateral) (assets)	[1]	(404)	0
Total net fair value of derivatives, assets		590	0
Liabilities		(2)	(1,087)
Less: Counterparty netting and cash deficit (collateral) (liabilities)	[1]	(2)	(290)
Total net fair value of derivative, liabilities		$ 0	$ (797)
Open derivative contracts (barrels) | bbl		82,000	370,000
Other current assets | Derivatives not designated as hedging instrument | Commodity derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Assets	[2]	$ 186	$ 0
Liabilities	[2]	$ (2)	$ (1,087)
[1]	As of December 31, 2018 and 2017 , we had cash collateral of $0.4 million and $0.3 million
[2]	As of December 31, 2018 and 2017 , we had open derivative contracts representing 82,000 barrels and 370,000

Derivative Instruments Income S

Derivative Instruments Income Statement Location (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Commodity derivatives | Purchases from Affiliates | Derivatives not designated as hedging instrument
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, gain (loss) on derivative, net	$ 3,325	$ (1,550)	$ (2,122)

Income Taxes Narrative (Details

Income Taxes Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Uncertain tax positions	$ 0	$ 0
Uncertain tax positions, income tax penalties and interest expense	0	0	$ 0
Other non-current assets
Deferred tax assets	300,000
Due to Related Parties
Taxes payable	$ 300,000	$ 400,000

Income Taxes Reconciliation of

Income Taxes Reconciliation of Actual Income Tax Expense to Statutory (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
State income taxes	$ 534	$ (222)	$ 121
Other items	0	0	(40)
Total	$ 534	$ (222)	$ 81

Income Taxes Components of Inco

Income Taxes Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Current	$ 382	$ (111)	$ 254
Deferred	152	(111)	(173)
Total	$ 534	$ (222)	$ 81

Commitments and Contingencies C

Commitments and Contingencies Crude Oil Releases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Nov. 30, 2018bbl	Mar. 15, 2018bbl	Feb. 28, 2018bbl	Mar. 31, 2013bbl
Loss Contingencies [Line Items]
Expense recorded, net of total reimbursable costs	$ 0.4
Smackover Release
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl				20
El Dorado Clean Harbors
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl					10
El Dorado February 2018 Release
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl						50
SALA Gathering System February 2018 Release - First
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl						250
Magnolia Station Spill
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl							5,900
Operating and maintenance expenses | Smackover Release
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies	1.5
Operating and maintenance expenses | Norphlet Release
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies	0.5
Delek US | Omnibus Agreement | Delek
Loss Contingencies [Line Items]
Recovery of direct costs	9.8
Delek US | Operating and maintenance expenses | Omnibus Agreement | Delek
Loss Contingencies [Line Items]
Recovery of direct costs	8.2	$ 0.3	$ 1.2
Other Current Liabilities | Magnolia Station Spill | Magnolia Station Spill
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies	$ 2.2

Commitments and Contingencies L

Commitments and Contingencies Letters of Credit (Details)	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Letters of credit	$ 0

Commitments and Contingencies O

Commitments and Contingencies Operating Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Operating leases, rent expense	$ 6,200	$ 5,600	$ 5,700
2,019	5,755
2,020	5,659
2,021	5,337
2,022	5,031
2,023	2,429
Thereafter	8
Total future minimum rentals	$ 24,219

Selected Quarterly Financial _3

Selected Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net revenues	$ 159,298	$ 164,110	$ 166,280	$ 167,921	$ 151,207	$ 130,626	$ 126,769	$ 129,473	$ 657,609	$ 538,075	$ 448,059
Operating income	31,147	32,624	34,710	27,277	23,698	22,636	23,371	18,472	125,757	88,177	77,650
Net income	21,280	23,326	25,582	19,995	18,914	16,923	18,977	14,595	90,182	69,409	62,804
Limited partners' interest in net income	$ 14,215	$ 16,690	$ 19,370	$ 14,365	$ 13,891	$ 12,178	$ 14,425	$ 10,486	$ 64,639	$ 50,980	$ 50,611
Common Units
Net income per limited partner unit:
Common (basic) (in usd per unit)	$ 0.58	$ 0.68	$ 0.79	$ 0.59	$ 0.57	$ 0.50	$ 0.59	$ 0.43	$ 2.65	$ 2.09	$ 2.08
Common units - (diluted) (in usd per unit)	$ 0.58	$ 0.68	$ 0.79	$ 0.59	$ 0.57	$ 0.50	$ 0.59	$ 0.43	$ 2.65	$ 2.09	$ 2.07

Subsequent Events (Details)

Subsequent Events (Details) - $ / shares	Feb. 12, 2019	Nov. 09, 2018	Aug. 13, 2018	May 15, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	Feb. 14, 2017
Subsequent Event [Line Items]
Cash distributions per limited partner unit (in usd per unit)		$ 0.790	$ 0.770	$ 0.750	$ 0.725	$ 0.715	$ 0.705	$ 0.690	$ 0.680
Subsequent Event
Subsequent Event [Line Items]
Cash distributions per limited partner unit (in usd per unit)	$ 0.810