Delek Logistics Partners (DKL) 10-Q 9 Aug 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Aug. 03, 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-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Common unitholders
Entity Information [Line Items]
Entity Partnership Units Outstanding		24,395,183
General Partner
Entity Information [Line Items]
Entity Partnership Units Outstanding		497,861

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 5,177	$ 4,675
Accounts receivable	21,881	23,013
Accounts receivable from related parties	9,651	1,124
Inventory	12,715	20,855
Other current assets	697	783
Total current assets	50,121	50,450
Property, plant and equipment:
Property, plant and equipment	446,961	367,179
Less: accumulated depreciation	(127,628)	(112,111)
Property, plant and equipment, net	319,333	255,068
Equity method investments	106,432	106,465
Goodwill	12,203	12,203
Intangible assets, net	157,643	15,917
Other non-current assets	4,617	3,427
Total assets	650,349	443,530
Current liabilities:
Accounts payable	9,319	19,147
Excise and other taxes payable	4,590	4,700
Tank inspection liabilities	902	902
Pipeline release liabilities	1,037	1,000
Accrued expenses and other current liabilities	5,282	6,033
Total current liabilities	21,130	31,782
Non-current liabilities:
Long-term debt	737,139	422,649
Asset retirement obligations	5,007	4,064
Other non-current liabilities	16,035	14,260
Total non-current liabilities	758,181	440,973
Deficit:
Total deficit	(128,962)	(29,225)
Total liabilities and deficit	650,349	443,530
Common unitholders | Common unitholders - public; 9,101,137 units issued and outstanding at June 30, 2018 (9,088,587 at December 31, 2017)
Deficit:
Total deficit	173,607	174,378
Common unitholders | Common unitholders - Delek; 15,294,046 units issued and outstanding at June 30, 2018 (15,294,046 at December 31, 2017)
Deficit:
Total deficit	(295,247)	(197,206)
General partner - 497,861 units issued and outstanding at June 30, 2018 (497,604 at December 31, 2017)
Deficit:
Total deficit	$ (7,322)	$ (6,397)

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parentheticals) - shares	Jun. 30, 2018	Dec. 31, 2017
General partner - Delek, units issued	497,861	497,604
General partner - Delek, units outstanding	497,861	497,604
Common unitholders - public
Common unitholders, units issued	9,101,137	9,088,587
Common unitholders, units outstanding	9,101,137	9,088,587
Common unitholders - Delek
Common unitholders, units issued	15,294,046	15,294,046
Common unitholders, units outstanding	15,294,046	15,294,046

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income and Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net revenues:
Affiliates	$ 53,080	$ 39,824	$ 114,724	$ 76,443
Third party	113,200	86,945	219,477	179,799
Total revenue	166,280	126,769	334,201	256,242
Operating costs and expenses:
Cost of goods sold	106,016	85,039	225,048	177,629
Operating expenses	14,917	9,966	27,494	20,324
General and administrative expenses	3,747	2,656	6,722	5,504
Depreciation and amortization	7,019	5,742	13,019	10,935
(Gain) loss on asset disposals	(129)	(5)	(69)	7
Total operating costs and expenses	131,570	103,398	272,214	214,399
Operating income	34,710	23,371	61,987	41,843
Interest expense, net	10,926	5,462	18,988	9,533
Income from equity method investments	(1,899)	(1,176)	(2,757)	(1,421)
Total non-operating expenses, net	9,027	4,286	16,231	8,112
Income before income tax expense	25,683	19,085	45,756	33,731
Income tax expense	101	108	179	159
Net income attributable to partners	25,582	18,977	45,577	33,572
Comprehensive income attributable to partners	25,582	18,977	45,577	33,572
Less: General partner's interest in net income, including incentive distribution rights	6,212	4,552	11,842	8,661
Limited partners' interest in net income	$ 19,370	$ 14,425	$ 33,735	$ 24,911
Weighted average limited partner units outstanding:
Cash distributions per limited partner unit (in dollars per share)	$ 0.770	$ 0.705	$ 1.52	$ 1.3950
Common Units
Net income per limited partner unit:
Common units - (basic) (in dollars per share)	0.79	0.59	1.38	1.02
Common units - (diluted) (in dollars per share)	$ 0.79	$ 0.59	$ 1.38	$ 1.02
Weighted average limited partner units outstanding:
Common units - (basic) (in shares)	24,386,031	24,335,338	24,384,341	24,331,991
Common units - (diluted) (in shares)	24,394,103	24,375,946	24,391,760	24,371,540

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Cash Flows ( Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities:
Net income	$ 45,577	$ 33,572
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	13,019	10,935
Amortization of other deferred charges	2,404	0
Amortization of deferred revenue	(723)	(601)
Amortization of deferred financing costs and debt discount	1,334	830
Accretion of asset retirement obligations	175	146
Deferred income taxes	0	119
Income from equity method investments	(2,757)	(1,421)
Dividends from equity method investments	2,302	278
(Gain) loss on asset disposals	(69)	7
Unit-based compensation expense	302	364
Changes in assets and liabilities:
Accounts receivable	1,132	932
Inventories and other current assets	8,226	2,041
Accounts payable and other current liabilities	(9,123)	1,479
Accounts receivable/payable to related parties	(8,446)	(1,352)
Non-current assets and liabilities, net	(1,710)	(419)
Net cash provided by operating activities	51,643	46,910
Cash flows from investing activities:
Purchase of Big Spring logistics assets, net of assumed ARO liabilities	(72,376)	0
Purchases of property, plant and equipment	(5,949)	(5,867)
Proceeds from sales of property, plant and equipment	356	0
Purchases of intangible assets	(144,219)	0
Distributions from equity method investments	660	501
Equity method investment contributions	(172)	(2,937)
Net cash used in investing activities	(221,700)	(8,303)
Cash flows from financing activities:
Proceeds from issuance of additional units to maintain 2% General Partner interest	13	21
Distributions to general partner	(10,810)	(8,231)
Distributions to common unitholders - public	(13,463)	(12,816)
Distributions to common unitholders - Delek	(22,558)	(20,772)
Distributions to Delek unitholders and general partner related to Big Spring Logistic Assets Acquisition	(98,798)	0
Proceeds from revolving credit facility	517,000	139,400
Payments of revolving credit facility	(203,000)	(377,500)
Proceeds from issuance of senior notes	0	248,112
Deferred financing costs paid	525	5,816
Reimbursement of capital expenditures by Delek	2,700	3,835
Net cash provided by (used in) financing activities	170,559	(33,767)
Net increase in cash and cash equivalents	502	4,840
Cash and cash equivalents at the beginning of the period	4,675	59
Cash and cash equivalents at the end of the period	5,177	4,899
Cash paid during the period for:
Interest	17,890	6,940
Income taxes	2	29
Non-cash investing activities:
Decrease in accrued capital expenditures	(1,529)	(957)
Non-cash financing activities:
Sponsor contribution of fixed assets	$ 0	$ 67

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows (Unaudited) (Parenthetical)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Cash Flows [Abstract]
General partner's ownership interest	2.00%	2.00%	2.00%	2.00%

Organization and Basis of Prese

Organization and Basis of Presentation	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Organization and Basis of Presentation As used in this report, the terms "Delek Logistics Partners, LP," the "Partnership," "we," "us," or "our" may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. The Partnership is a Delaware limited partnership formed in April 2012 by Old Delek (as defined below) and its subsidiary Delek Logistics GP, LLC, our general partner (our "general partner"). In January 2017, Delek US Holdings, Inc. ("Old Delek") (and various related entities) entered into an Agreement and Plan of Merger with Alon USA Energy, Inc. (NYSE: ALJ) ("Alon USA"), as subsequently amended on February 27 and April 21, 2017 (as so amended, the "Merger Agreement"). The related merger (the "Delek/Alon Merger") was effective July 1, 2017 (the “Effective Time”), resulting in a new post-combination consolidated registrant renamed Delek US Holdings, Inc. (“New Delek”), with Alon USA and Old Delek surviving as wholly-owned subsidiaries. New Delek is the successor issuer to Old Delek and Alon USA pursuant to Rule 12g-3(c) under the Securities Exchange Act of 1934, as amended (the "Exchange Act"). Unless the context otherwise requires, references in this report to "Delek" refer collectively to Old Delek with respect to periods prior to July 1, 2017, or New Delek, with respect to periods on or after July 1, 2017, and any of Old Delek's or New Delek's, as applicable, subsidiaries, other than the Partnership and its subsidiaries and its general partner. Effective March 1, 2018 , the Partnership, through its wholly-owned subsidiary DKL Big Spring, LLC, acquired from Delek certain logistics assets primarily located at or adjacent to Delek's refinery near Big Spring, Texas (the "Big Spring Refinery") and Delek's light products distribution terminal located in Stephens County, Oklahoma (collectively, the "Big Spring Logistic Assets"), such transaction the "Big Spring Logistic Assets Acquisition." See Note 2 for further information regarding the Big Spring Logistic Assets Acquisition. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles ("U.S. GAAP") have been condensed or omitted, although management believes that the disclosures herein are adequate to make the financial information presented not misleading. Our unaudited condensed consolidated financial statements have been prepared in conformity with U.S. GAAP applied on a consistent basis with those of the annual audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2017 (our "Annual Report on Form 10-K"), filed with the Securities and Exchange Commission (the "SEC") on March 1, 2018. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2017 included in our Annual Report on Form 10-K. In the opinion of management, all adjustments necessary for a fair presentation of the financial position and the results of operations for the interim periods presented have been included. All significant intercompany transactions and account balances have been eliminated in the consolidation. Such intercompany transactions do not include those with Delek or our general partner. All adjustments are of a normal, recurring nature. Operating results for the interim period should not be viewed as representative of results that may be expected for any future interim period or for the full year. New Accounting Pronouncements 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. 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. 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. 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. We expect to adopt this guidance on or before the effective date and we do not anticipate that the adoption will have a material impact on our business, financial condition or results of operations. 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 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 distributions 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 $0.5 million of distributions received in the six months ended June 30, 2017 from the line item entitled dividends from equity method investments in net cash provided by operating activities to the line item entitled distributions from equity method investments in net cash used in investing activities in the condensed consolidated statements of cash flows. 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. Lessor accounting will remain substantially similar to current guidance. This guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. In January 2018, the FASB amended the guidance to provide an optional practical expedient to rights of way. The practical expedient permits an entity to not evaluate under the new lease accounting guidance existing or expired rights of way that were not previously accounted for as leases. However, any new or modified rights of way should be evaluated under the new lease accounting guidance. If not elected, an entity should evaluate all existing or expired rights of way in connection with the adoption of the new lease requirement to assess whether they meet the definition of a lease. In July 2018, the FASB amended the guidance to provide a practical expedient regarding the requirement to recast prior periods for the new lease guidance. If elected, comparative periods in transition are not required to be recast, and a cumulative effect of initially applying the guidance will be recognized to the opening balance of retained earnings in the period of adoption. If not elected, we are required to use the modified retrospective adoption method to apply this guidance, under which the cumulative effect of initially applying the guidance will be recognized as an adjustment to the opening balance of retained earnings in the earliest period presented as of the adoption period. We expect to adopt the new lease standard on January 1, 2019 and elect the practical expedient regarding transition. We are currently evaluating the impact adopting this new guidance will have on our business, financial condition and results of operations. As part of our efforts to prepare for adoption, beginning in 2018, we formed a project implementation team, as well as a project timeline, to evaluate this guidance. We have also reviewed and gained an understanding of the new lease accounting guidance and substantially completed lease classification analysis for existing leases. We continue to perform scoping to identify and evaluate arrangements that will qualify as leases under the new standard, as well as to review industry specific implementation guidance. We are continuing to evaluate the impact of the guidance on our business processes, accounting systems, controls and financial statement disclosures, and expect to implement any changes to accommodate the new accounting and disclosure requirements prior to adoption on January 1, 2019. 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. 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. The Partnership has updated its policies as it relates to 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 a service to a customer. The adoption of ASC 606 did not materially change our revenue recognition patterns. Revenues for products sold are generally recognized upon delivery of the 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 product 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 are considered operating leases under ASC 840, Leases . 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 4 for further information. 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 . 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 from a customer. Historically, we have excluded sales, use and excise taxes from revenue in accordance with the applicable guidance in ASC 605, Revenue Recognition .

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2018
Acquisitions [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, which are primarily located at or adjacent to the Big Spring Refinery. The total purchase price was $170.8 million , subject to certain post-closing adjustments, 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, 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 3 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's historical carrying value as of the acquisition date. The excess of the cash paid over the historical book value of the assets acquired from Delek amounted to $98.8 million and was recorded in equity. The 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 liabilities. Prior periods have not been recast, as these assets do 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 six months ended June 30, 2018 . We did not capitalize any acquisition costs during the three months ended June 30, 2018 . Marketing Contract Intangible Acquisition Additionally, concurrent with the Big Spring Logistic Assets Acquisition, Delek, the Partnership and various of their respective subsidiaries entered into a new marketing agreement, whereby the Partnership markets certain finished 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 will be 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 3 for a more detailed description of this marketing agreement.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 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 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. 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. In November 2017, Delek 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 in respect to the Tyler refinery, the initial term has been extended through 2026. The fees under each agreement are payable to us monthly by Delek or certain third parties to whom Delek 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 or the applicable third party assignee fails to meet or exceed the minimum volume or throughput commitment during any calendar quarter, Delek, and not any third party assignee, will be required to make a quarterly shortfall payment to us equal to the volume of the shortfall multiplied by the applicable fee, 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. See our Annual Report on Form 10-K for a more complete description of certain of our commercial agreements and other agreements with Delek. During the six months ended June 30, 2018 , we entered into the following material agreements with Delek: Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (2) 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/bbl Rail Offloading March 1, 2018 10/15 Offloading Services 4,500 $0.40/bbl Terminalling March 1, 2018 10/15 Dedicated Terminalling Services 29,250 $0.66/bbl Storage March 1, 2018 10/15 Storage N/A $1,374,630/month Asphalt Services Agreement (Big Spring): Terminalling March 1, 2018 10/15 Dedicated Asphalt Terminalling 1,020 to 2,380 based on seasonality $8.30/bbl Storage March 1, 2018 10/15 Storage 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/bbl (1) Maximum term gives effect to the extension by (i) the Partnership of the Pipelines, Storage and Throughput Facilities Agreement and Asphalt Services Agreement pursuant to the terms thereof and (ii) Delek of the Marketing Agreement pursuant to the terms thereof. Maximum term excludes the impact of the automatic annual renewal of these agreements, unless terminated by either party, subsequent to the extension. (2) Fees payable to the Partnership by Delek. 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 (“Alon USA, LP”), and DKL Big Spring, LLC, a Delaware limited liability company and a wholly-owned subsidiary of the Partnership (the "Buyer"), 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 Buyer will provide storage and throughput services at certain of the Big Spring Logistic Assets for Alon USA, LP. The Buyer 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 Buyer. The Buyer 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 Buyer 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 Buyer entered into the Big Spring Asphalt Services Agreement (the “Asphalt Services Agreement”). Under the Asphalt Services Agreement, the Buyer will provide asphalt storage and handling services at certain of the Big Spring Logistic Assets (such assets, the “Asphalt Facilities”). The Buyer 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 Buyer 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 Buyer 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 Buyer entered into the Marketing Agreement (the “Marketing Agreement”). Under the Marketing Agreement, the Buyer will provide Alon USA, LP with services for the marketing and selling of certain refined petroleum products that are produced or sold from the refinery near Big Spring, Texas. The Buyer 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. Omnibus Agreement. The Partnership entered into an omnibus agreement with Delek, our general partner, Delek Logistics Operating, LLC, Lion Oil Company and certain of the Partnership's and Delek's other subsidiaries on November 7, 2012, which was subsequently amended and restated on July 26, 2013, February 10, 2014, 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"). In conjunction with the March 1, 2018 amendment, our obligation to pay an annual fee to Delek for its provision of centralized corporate services to the Partnership was increased to $ 3.9 million annually. Pursuant to the terms of the Omnibus Agreement, we were reimbursed by Delek for certain capital expenditures in the amount of $0.4 million and $2.7 million during the three and six months ended June 30, 2018 , respectively, and $0.8 million and $3.8 million during the three and six months ended June 30, 2017 , 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. Ad ditionally, we were 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 Agreeme nt. As of June 30, 2018 , we have recorded an increase to accounts receivable from related parties of $7.8 million for these matters for which we were or expect to be reimbursed, which was recorded as a reduction to operating expense. We were reimbursed $0.1 million for these matters during each of the three and six months ended June 30, 2018 . We were reimbursed $0.3 million and $0.4 million for these matters during the three and six months ended June 30, 2017 . 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 based on regulated tariff rates or contractually based fees and product sales. Affiliate operating expenses are primarily comprised of amounts we reimburse Delek, or our general partner, as the case may be, for the services provided to us under the First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement"). These expenses could also include reimbursement and indemnification amounts from Delek, as provided under the Omnibus Agreement. Additionally, the Partnership is required to reimburse Delek for direct or allocated costs and expenses incurred by Delek on behalf of the Partnership and for charges Delek incurred for the management and operation of our logistics assets, including an annual fee for various centralized corporate services, which are included in general and administrative services. In addition to these transactions, we purchase finished products and bulk biofuels from Delek, the costs of which are included in cost of goods sold. A summary of revenue, purchases from affiliates and expense transactions with Delek and its affiliates is as follows (in thousands) Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Revenues $ 53,080 $ 39,824 $ 114,724 $ 76,443 Purchases from affiliates $ 99,515 $ 8,252 $ 181,715 $ 17,180 Operating and maintenance expenses $ 11,422 $ 6,385 $ 18,911 $ 13,481 General and administrative expenses $ 2,505 $ 1,561 $ 3,462 $ 3,254 Quarterly Cash Distributions Our common and general partner unitholders and the holders of incentive distribution rights ("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. In February and May 2018 , we paid quarterly cash distributions of $22.8 million and $24.0 million , respectively, of which $16.2 million and $17.2 million , respectively, were paid to Delek and our general partner. In February and May 2017 , we paid quarterly cash distributions of $20.5 million and $21.0 million , of which $14.2 million and $14.7 million , respectively, were paid to Delek and our general partner. On July 24, 2018 , our general partner's board of directors declared a quarterly cash distribution totaling $25.0 million , based on the available cash as of the date of determination for the end of the second quarter of 2018 , payable on August 13, 2018 , of which $18.0 million is expected to be paid to Delek and our general partner, including the payment for the IDRs.

Revenues (Notes)

Revenues (Notes)	6 Months Ended
	Jun. 30, 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's 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, which provide for annual fee adjustments for increases or decreases in the CPI, PPI or FERC index (refer to Note 3 for a more detailed description of these agreements). In addition to the services we provide to Delek, 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, 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. The majority of our commercial agreements with Delek 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 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): Three Months Ended June 30, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 3,714 $ 493 $ 4,207 Service Revenue - Affiliate (1) 23,160 14,581 37,741 Product Revenue - Third Party — 108,993 108,993 Product Revenue - Affiliate — 794 794 Lease Revenue - Affiliate 10,870 3,675 14,545 Total Revenue $ 37,744 $ 128,536 $ 166,280 Six Months Ended June 30, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 7,965 $ 802 $ 8,767 Service Revenue - Affiliate (1) 43,057 24,147 67,204 Product Revenue - Third Party — 210,710 210,710 Product Revenue - Affiliate — 21,028 21,028 Lease Revenue - Affiliate 20,435 6,057 26,492 Total Revenue $ 71,457 $ 262,744 $ 334,201 _____________________________ (1) Net of $1.8 million and $2.4 million of amortization expense for the three and six months ended, respectively, related to a customer contract intangible asset recorded in the wholesale marketing and terminalling segment. As of June 30, 2018 , we expect to recognize $ 1.2 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. 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 June 30, 2018 were as follows (in millions): Remainder of 2018 $ 87,828 2019 164,646 2020 164,295 2021 153,541 2022 and thereafter 635,164 Total expected revenue on remaining performance obligations $ 1,205,474

Inventory

Inventory	6 Months Ended
	Jun. 30, 2018
Inventory Disclosure [Abstract]
Inventory	Inventory Inventories consisted of $12.7 million and $20.9 million of refined petroleum products as of June 30, 2018 and December 31, 2017 , respectively. Inventory is stated at the lower of cost or net realizable value, with cost determined on a first-in, first-out basis. We recognize lower of cost or net realizable value charges as a component of cost of goods sold in the consolidated statements of income and comprehensive income, which amounted to a nominal amount during both three and six month periods ended June 30, 2018 and 2017 .

Long-Term Obligations

Long-Term Obligations	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Long-Term Obligations	Long-Term Obligations DKL Revolver We have a $700.0 million senior secured revolving credit agreement with Fifth Third Bank, as administrative agent, and a syndicate of lenders (the "DKL Revolver"). The DKL Revolver contains a dual currency borrowing tranche that permits draw downs in U.S. or Canadian dollars and an accordion feature whereby the Partnership may increase the size of the credit facility to an aggregate of $800.0 million , subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. The obligations under the DKL Revolver are secured by first priority liens on substantially all of the Partnership's and its subsidiaries' tangible and intangible assets. Additionally, Delek Marketing & Supply, LLC ("Delek Marketing"), a wholly-owned subsidiary of Delek, provides a limited guaranty of the Partnership's obligations under the DKL Revolver. Delek Marketing's guaranty is (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek US in favor of Delek Marketing (the "Holdings Note") and (ii) secured by Delek Marketing's pledge of the Holdings Note to the DKL Revolver lenders. As of both June 30, 2018 and December 31, 2017 , the principal amount of the Holdings Note was $102.0 million . The DKL Revolver has a maturity date of December 30, 2019. 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 varies 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 credit facility. At June 30, 2018 , the weighted average interest rate for our borrowings under the facility was approximately 4.9% . Additionally, the DKL Revolver requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of June 30, 2018 , this fee was 0.5% per year. As of June 30, 2018 , we had $493.9 million of outstanding borrowings under the DKL Revolver, with no letters of credit in place. Unused credit commitments under the DKL Revolver as of June 30, 2018 , were $206.1 million . 6.75% 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 are substantially identical to the terms of the original 2025 Notes. As of June 30, 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 $5.1 million and $1.6 million , respectively, as of June 30, 2018 , and $5.5 million and $1.7 million , respectively, as of December 31, 2017 .

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 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.

Net Income Per Unit

Net Income Per Unit	6 Months Ended
	Jun. 30, 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, 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 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 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. At present, the only potentially dilutive units outstanding consist of unvested phantom units. 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 expected date of distribution for the distributions earned during the period ended June 30, 2018 is August 13, 2018 . The calculation of net income per unit is as follows (dollars in thousands, except units and per unit amounts): Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 Net income attributable to partners $ 25,582 $ 18,977 $ 45,577 $ 33,572 Less: General partner's distribution (including IDRs) (1) 6,200 4,608 11,910 8,845 Less: Limited partners' distribution 18,784 17,175 37,071 33,962 Earnings in excess (deficit) of distributions $ 598 $ (2,806 ) $ (3,404 ) $ (9,235 ) General partner's earnings: Distributions (including IDRs) (1) $ 6,200 $ 4,608 $ 11,910 $ 8,845 Allocation of earnings in excess (deficit) of distributions 12 (56 ) (68 ) (184 ) Total general partner's earnings $ 6,212 $ 4,552 $ 11,842 $ 8,661 Limited partners' earnings on common units: Distributions $ 18,784 $ 17,175 $ 37,071 $ 33,962 Allocation of earnings in excess (deficit) of distributions 586 (2,750 ) (3,336 ) (9,051 ) Total limited partners' earnings on common units $ 19,370 $ 14,425 $ 33,735 $ 24,911 Weighted average limited partner units outstanding (2) : Common units - (basic) 24,386,031 24,335,338 24,384,341 24,331,991 Common units - (diluted) 24,394,103 24,375,946 24,391,760 24,371,540 Net income per limited partner unit (2) : Common units - (basic) $ 0.79 $ 0.59 $ 1.38 $ 1.02 Common units - (diluted) $ 0.79 $ 0.59 $ 1.38 $ 1.02 (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 9 for further discussion related to IDRs. (2) We base our calculation of net income per unit on the weighted-average number of common limited partner units outstanding during the period.

Equity

Equity	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Equity	Equity We had 9,101,137 common limited partner units held by the public outstanding as of June 30, 2018 . Additionally, as of June 30, 2018 , Delek 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 497,861 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 The table below summarizes the changes in the number of units outstanding from December 31, 2017 through June 30, 2018 . Common - Public Common - Delek General Partner Total Balance at December 31, 2017 9,088,587 15,294,046 497,604 24,880,237 General partner units issued to maintain 2% interest — — 257 257 Unit-based compensation awards (1) 12,550 — — 12,550 Balance at June 30, 2018 9,101,137 15,294,046 497,861 24,893,044 (1) Unit-based compensation awards are presented net of 598 units withheld for taxes. The summarized changes in the carrying amount of our equity from December 31, 2017 through June 30, 2018 are as follows (in thousands): Common - Public Common - Delek General Partner Total Balance at December 31, 2017 $ 174,378 $ (197,206 ) $ (6,397 ) $ (29,225 ) Distributions to unitholders and general partner related to Big Spring Logistic Assets Acquisition — (96,822 ) (1,976 ) (98,798 ) Cash distributions (1) (13,463 ) (22,558 ) (10,810 ) (46,831 ) Net income attributable to partners 12,581 21,154 11,842 45,577 Unit-based compensation 111 185 6 302 Other — — 13 13 Balance at June 30, 2018 $ 173,607 $ (295,247 ) $ (7,322 ) $ (128,962 ) (1) Cash distributions include $0.1 million related to distribution equivalents on vested phantom units. 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): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Net income attributable to partners $ 25,582 $ 18,977 $ 45,577 $ 33,572 Less: General partner's IDRs (5,817 ) (4,258 ) (11,154 ) (8,153 ) Net income available to partners $ 19,765 $ 14,719 $ 34,423 $ 25,419 General partner's ownership interest 2.0 % 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income $ 395 $ 294 $ 688 $ 508 General partner's IDRs 5,817 4,258 11,154 8,153 Total general partner's interest in net income $ 6,212 $ 4,552 $ 11,842 $ 8,661 Incentive Distribution Rights The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and our unitholders in any available cash from operating surplus that we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that (i) our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and (ii) our general partner has not transferred its IDRs. Target Quarterly Distribution per Unit Marginal Percentage Interest in Distributions Target Amount Unitholders General Partner Minimum Quarterly Distribution $ 0.37500 98.0 % 2.0 % First Target Distribution above $ 0.37500 98.0 % 2.0 % up to $ 0.43125 Second Target Distribution above $ 0.43125 85.0 % 15.0 % up to $ 0.46875 Third Target Distribution above $ 0.46875 75.0 % 25.0 % up to $ 0.56250 Thereafter thereafter $ 0.56250 50.0 % 50.0 % Cash Distributions Our Partnership Agreement sets forth the calculation to be used to determine the amount and priority of 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 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 (1) August 3, 2018 (1) Expected date of distribution. The allocation of total quarterly cash distributions expected to be made on August 13, 2018 to general and limited partners for the three and six months ended June 30, 2018 and the allocation of total quarterly cash distributions for the three and six months ended June 30, 2017 are 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): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 General partner's distributions: General partner's distributions $ 383 $ 350 $ 756 $ 692 General partner's IDRs 5,817 4,258 11,154 8,153 Total general partner's distributions 6,200 4,608 11,910 8,845 Limited partners' distributions: Common limited partners' distributions 18,784 17,175 37,071 33,962 Total cash distributions $ 24,984 $ 21,783 $ 48,981 $ 42,807 Cash distributions per limited partner unit $ 0.770 $ 0.705 $ 1.520 $ 1.395

Equity Based Compensation

Equity Based Compensation	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity Based Compensation	Equity Based Compensation We incurred approximately $0.2 million and $0.3 million of unit-based compensation expense related to the Partnership during the three and six months ended June 30, 2018 , respectively, and $0.2 million and $0.4 million of unit-based compensation expense related to the Partnership during the three and six months ended June 30, 2017 , respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income and comprehensive income. The fair value of phantom unit awards under the Delek Logistics GP, LLC 2012 Long-Term Incentive Plan (the "LTIP") is determined based on the closing price of our common limited partner units on the grant date of the awards. 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 of June 30, 2018 , there was $0.6 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 0.9 years.

Equity Method Investments

Equity Method Investments	6 Months Ended
	Jun. 30, 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. 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 RIO") to operate the other pipeline system. The Partnership's investments in these two entities were financed through a combination of cash from operations and borrowings under the DKL Revolver. As of June 30, 2018 and December 31, 2017 , the Partnership's investment balance in these joint ventures was $106.4 million and $106.5 million , respectively. In February 2018 , the Partnership and an affiliate of Green Plains Partners LP ("Green Plains") entered into a joint venture engaging in the light products terminalling business. The companies formed DKGP Energy Terminals, LLC ("DKGP Energy"). The Partnership and Green Plains each own a 50% membership interest in DKGP Energy. DKGP Energy signed a membership interest purchase agreement (the "Membership Interest Purchase Agreement") to acquire two light products terminals located in Caddo Mills, Texas and North Little Rock, Arkansas from an affiliate of American Midstream Partners, L.P. ("American Midstream"), subject to certain closing conditions and regulatory approvals (the "DKGP Transaction"). The Membership Interest Purchase Agreement expired on August 1, 2018 pursuant to its terms (primarily due to delays in receiving federal regulatory approval for the acquisition), and the contemplated DKGP Transaction terminated (the "DKGP Termination"). As a result of the DKGP Termination, the contemplated contribution of certain of the Partnership's terminals to DKGP Energy, in connection with the DKGP Transaction, terminated. At this time the Partnership and Green Plains do not have any further transaction or development plans with respect to DKGP Energy. 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 Rangeland RIO, 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): June 30, 2018 December 31, 2017 Current assets $ 18,195 $ 12,671 Non-current assets $ 241,564 $ 244,329 Current liabilities $ 3,876 $ 1,798 Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Revenues $ 9,886 $ 7,022 $ 17,876 $ 12,693 Gross profit $ 9,886 $ 7,022 $ 17,876 $ 12,693 Net income $ 4,800 $ 3,379 $ 7,512 $ 4,392

Segment Data

Segment Data	6 Months Ended
	Jun. 30, 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 finished products transportation and storage services to Delek's refining operations and independent third parties. • The wholesale marketing and terminalling segment provides wholesale marketing and terminalling services to Delek's refining operations and independent third parties. Our operating segments adhere to the accounting policies used for our consolidated financial statements. 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 goods sold and operating expenses. The following is a summary of business segment operating performance as measured by contribution margin for the periods indicated (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 Pipelines and Transportation Net revenues: Affiliates $ 34,030 $ 27,668 $ 63,492 $ 54,168 Third party 3,714 2,555 7,965 4,732 Total pipelines and transportation 37,744 30,223 71,457 58,900 Operating costs and expenses: Cost of goods sold 5,195 4,403 9,636 8,808 Operating expenses 9,933 7,933 19,555 16,088 Segment contribution margin $ 22,616 $ 17,887 $ 42,266 $ 34,004 Capital spending (1) $ 826 $ 1,660 $ 2,234 $ 3,797 Wholesale Marketing and Terminalling Net revenues: Affiliates (2) $ 19,050 $ 12,156 $ 51,232 $ 22,275 Third party 109,486 84,390 211,512 175,067 Total wholesale marketing and terminalling 128,536 96,546 262,744 197,342 Operating costs and expenses: Cost of goods sold 100,821 80,636 215,412 168,821 Operating expenses 4,984 2,033 7,939 4,236 Segment contribution margin $ 22,731 $ 13,877 $ 39,393 $ 24,285 Capital spending (1) $ 1,426 $ 459 $ 2,215 $ 1,113 Consolidated Net revenues: Affiliates $ 53,080 $ 39,824 $ 114,724 $ 76,443 Third party 113,200 86,945 219,477 179,799 Total consolidated 166,280 126,769 334,201 256,242 Operating costs and expenses: Cost of goods sold 106,016 85,039 225,048 177,629 Operating expenses 14,917 9,966 27,494 20,324 Contribution margin 45,347 31,764 81,659 58,289 General and administrative expenses 3,747 2,656 6,722 5,504 Depreciation and amortization 7,019 5,742 13,019 10,935 Loss (gain) on asset disposals (129 ) (5 ) (69 ) 7 Operating income $ 34,710 $ 23,371 $ 61,987 $ 41,843 Capital spending (1) $ 2,252 $ 2,119 $ 4,449 $ 4,910 (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 six months ended June 30, 2018 . No costs were capitalized during the three months ended June 30, 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 June 30, 2018 and December 31, 2017 (in thousands): June 30, 2018 December 31, 2017 Pipelines and transportation $ 439,311 $ 349,351 Wholesale marketing and terminalling 211,038 94,179 Total assets $ 650,349 $ 443,530 Property, plant and equipment and accumulated depreciation as of June 30, 2018 and depreciation expense by reporting segment for the three and six months ended June 30, 2018 were as follows (in thousands): Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 362,128 $ 84,833 $ 446,961 Less: accumulated depreciation (96,915 ) (30,713 ) (127,628 ) Property, plant and equipment, net $ 265,213 $ 54,120 $ 319,333 Depreciation expense for the three months ended June 30, 2018 $ 5,594 $ 1,336 $ 6,930 Depreciation expense for the six months ended June 30, 2018 $ 10,524 $ 2,406 $ 12,930 In accordance with Accounting Standards Codification ("ASC") 360, Property, Plant & Equipment , we evaluate the realizability of property, plant and equipment as events occur that might indicate potential impairment. There were no indicators of impairment of our property, plant and equipment as of June 30, 2018 .

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 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 , which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to commodity and interest rate 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 and any interest rate swaps 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 June 30, 2018 and December 31, 2017 was as follows (in thousands): As of June 30, 2018 Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ — $ 2 $ — $ 2 Total assets — 2 — 2 Liabilities Commodity derivatives — (380 ) — (380 ) Net liabilities $ — $ (378 ) $ — $ (378 ) 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 June 30, 2018 and December 31, 2017 , we had cash collateral of $0.5 million and $0.3 million , respectively, netted with the net derivative position of our counterparty. See Note 14 for further information regarding derivative instruments.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 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 finished 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 finished grade fuel for a predetermined number of units with fulfillment terms of less than 90 days. From time to time, we may also enter into interest rate hedging agreements to limit floating interest rate exposure under the DKL Revolver. The following table presents the fair value of our derivative instruments as of June 30, 2018 and December 31, 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 condensed consolidated balance sheets. During the three and six months ended June 30, 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 condensed consolidated statements of income and comprehensive income. See Note 13 for further information regarding the fair value of derivative instruments. (in thousands) June 30, 2018 December 31, 2017 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives: Commodity derivatives (1) Accrued expenses and other current liabilities $ 2 $ (380 ) $ — $ (1,087 ) Total gross fair value of derivatives 2 (380 ) — (1,087 ) Less: Counterparty netting and cash collateral (deficit) (2) (88 ) (380 ) — (290 ) Total net fair value of derivatives $ 90 $ — $ — $ (797 ) (1) As of June 30, 2018 and December 31, 2017 , we had open derivative contracts representing 117,000 barrels and 370,000 barrels, respectively, of refined petroleum products. (2) As of June 30, 2018 and December 31, 2017 , we had cash collateral of $0.5 million and $0.3 million , respectively, netted with the net derivative position of our counterparty. Recognized gains (losses) associated with our derivatives for the three and six months ended June 30, 2018 and 2017 were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, Derivative Type Income Statement Location 2018 2017 2018 2017 Commodity derivatives Cost of goods sold $ (843 ) $ 606 $ 740 $ 1,116

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 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 business, financial condition or results of operations. See "Crude Oil Releases" below for further discussion. 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, 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: • In February 2018, a release of approximately 203 barrels of crude oil, occurred from our SALA Gathering System near Urbana, Arkansas Station. • 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, although 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. Expenses incurred for the remediation of these crude oil releases are included in operating expenses in our condensed consolidated statements of income and comprehensive income and are subsequently reimbursed by Delek 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 for such costs. During each of the three and six months ended June 30, 2018 , we recorded approximately $0.1 million of expense, which is net of total expected reimbursements from Delek pursuant to the terms of the Omnibus Agreement of $7.8 million , 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, are currently 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. Although we have been negotiating a resolution to this matter with the EPA and the State of Arkansas, which will include monetary penalties and other relief, 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 July 13, 2018. As of June 30, 2018 , we have accrued $1.0 million , which we recorded in pipeline release liabilities in our condensed consolidated balance sheet, for the Magnolia Release in connection with these proceedings. We believe this amount is adequate to cover our expected obligations related to these proceedings and that these proceedings will not have a material adverse effect upon the Partnership's business, financial condition or result of operations. 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 (the "Abilene 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 exchange with third parties at the Abilene and San Angelo 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 . In the first half of 2018 , we purchased spot barrels from various third parties and from Delek for sale to wholesale customers in west Texas. Letters of Credit At June 30, 2018 , we had no letters of credit in place under the DKL Revolver.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Distribution Declaration On July 24, 2018 , our general partner's board of directors declared a quarterly cash distribution of $0.77 per limited partner unit, payable on August 13, 2018 , to unitholders of record on August 3, 2018 .

Organization and Basis of Pre23

Organization and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting	Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles ("U.S. GAAP") have been condensed or omitted, although management believes that the disclosures herein are adequate to make the financial information presented not misleading. Our unaudited condensed consolidated financial statements have been prepared in conformity with U.S. GAAP applied on a consistent basis with those of the annual audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2017 (our "Annual Report on Form 10-K"), filed with the Securities and Exchange Commission (the "SEC") on March 1, 2018. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2017 included in our Annual Report on Form 10-K.
Consolidation	In the opinion of management, all adjustments necessary for a fair presentation of the financial position and the results of operations for the interim periods presented have been included. All significant intercompany transactions and account balances have been eliminated in the consolidation. Such intercompany transactions do not include those with Delek or our general partner. All adjustments are of a normal, recurring nature. Operating results for the interim period should not be viewed as representative of results that may be expected for any future interim period or for the full year.
New Accounting Pronouncements	New Accounting Pronouncements 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. 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. 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. 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. We expect to adopt this guidance on or before the effective date and we do not anticipate that the adoption will have a material impact on our business, financial condition or results of operations. 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 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 distributions 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 $0.5 million of distributions received in the six months ended June 30, 2017 from the line item entitled dividends from equity method investments in net cash provided by operating activities to the line item entitled distributions from equity method investments in net cash used in investing activities in the condensed consolidated statements of cash flows. 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. Lessor accounting will remain substantially similar to current guidance. This guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. In January 2018, the FASB amended the guidance to provide an optional practical expedient to rights of way. The practical expedient permits an entity to not evaluate under the new lease accounting guidance existing or expired rights of way that were not previously accounted for as leases. However, any new or modified rights of way should be evaluated under the new lease accounting guidance. If not elected, an entity should evaluate all existing or expired rights of way in connection with the adoption of the new lease requirement to assess whether they meet the definition of a lease. In July 2018, the FASB amended the guidance to provide a practical expedient regarding the requirement to recast prior periods for the new lease guidance. If elected, comparative periods in transition are not required to be recast, and a cumulative effect of initially applying the guidance will be recognized to the opening balance of retained earnings in the period of adoption. If not elected, we are required to use the modified retrospective adoption method to apply this guidance, under which the cumulative effect of initially applying the guidance will be recognized as an adjustment to the opening balance of retained earnings in the earliest period presented as of the adoption period. We expect to adopt the new lease standard on January 1, 2019 and elect the practical expedient regarding transition. We are currently evaluating the impact adopting this new guidance will have on our business, financial condition and results of operations. As part of our efforts to prepare for adoption, beginning in 2018, we formed a project implementation team, as well as a project timeline, to evaluate this guidance. We have also reviewed and gained an understanding of the new lease accounting guidance and substantially completed lease classification analysis for existing leases. We continue to perform scoping to identify and evaluate arrangements that will qualify as leases under the new standard, as well as to review industry specific implementation guidance. We are continuing to evaluate the impact of the guidance on our business processes, accounting systems, controls and financial statement disclosures, and expect to implement any changes to accommodate the new accounting and disclosure requirements prior to adoption on January 1, 2019. 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. 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
Inventory	Inventory is stated at the lower of cost or net realizable value, with cost determined on a first-in, first-out basis.
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, 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 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 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.
Segment Data	Our operating segments adhere to the accounting policies used for our consolidated financial statements. 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 goods sold and operating expenses
Property, Plant and Equipment, Impairment	In accordance with Accounting Standards Codification ("ASC") 360, Property, Plant & Equipment , we evaluate the realizability of property, plant and equipment as events occur that might indicate potential impairment.
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 , which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to commodity and interest rate 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 and any interest rate swaps 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.
Revenue Recognition, Policy [Policy Text Block]	The Partnership has updated its policies as it relates to 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 a service to a customer. The adoption of ASC 606 did not materially change our revenue recognition patterns. Revenues for products sold are generally recognized upon delivery of the 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 product 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 are considered operating leases under ASC 840, Leases . 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 4 for further information. 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 . 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 from a customer. Historically, we have excluded sales, use and excise taxes from revenue in accordance with the applicable guidance in ASC 605, Revenue Recognition .

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Commercial Agreements	During the six months ended June 30, 2018 , we entered into the following material agreements with Delek: Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (2) 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/bbl Rail Offloading March 1, 2018 10/15 Offloading Services 4,500 $0.40/bbl Terminalling March 1, 2018 10/15 Dedicated Terminalling Services 29,250 $0.66/bbl Storage March 1, 2018 10/15 Storage N/A $1,374,630/month Asphalt Services Agreement (Big Spring): Terminalling March 1, 2018 10/15 Dedicated Asphalt Terminalling 1,020 to 2,380 based on seasonality $8.30/bbl Storage March 1, 2018 10/15 Storage 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/bbl (1) Maximum term gives effect to the extension by (i) the Partnership of the Pipelines, Storage and Throughput Facilities Agreement and Asphalt Services Agreement pursuant to the terms thereof and (ii) Delek of the Marketing Agreement pursuant to the terms thereof. Maximum term excludes the impact of the automatic annual renewal of these agreements, unless terminated by either party, subsequent to the extension. (2) Fees payable to the Partnership by Delek.
Summary of Related Party Transactions	A summary of revenue, purchases from affiliates and expense transactions with Delek and its affiliates is as follows (in thousands) Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Revenues $ 53,080 $ 39,824 $ 114,724 $ 76,443 Purchases from affiliates $ 99,515 $ 8,252 $ 181,715 $ 17,180 Operating and maintenance expenses $ 11,422 $ 6,385 $ 18,911 $ 13,481 General and administrative expenses $ 2,505 $ 1,561 $ 3,462 $ 3,254

Revenues (Tables)

Revenues (Tables)	6 Months Ended
	Jun. 30, 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): Three Months Ended June 30, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 3,714 $ 493 $ 4,207 Service Revenue - Affiliate (1) 23,160 14,581 37,741 Product Revenue - Third Party — 108,993 108,993 Product Revenue - Affiliate — 794 794 Lease Revenue - Affiliate 10,870 3,675 14,545 Total Revenue $ 37,744 $ 128,536 $ 166,280 Six Months Ended June 30, 2018 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Service Revenue - Third Party $ 7,965 $ 802 $ 8,767 Service Revenue - Affiliate (1) 43,057 24,147 67,204 Product Revenue - Third Party — 210,710 210,710 Product Revenue - Affiliate — 21,028 21,028 Lease Revenue - Affiliate 20,435 6,057 26,492 Total Revenue $ 71,457 $ 262,744 $ 334,201 _____________________________ (1) Net of $1.8 million and $2.4 million of amortization expense for the three and six months ended, respectively, related to a customer contract intangible asset recorded in the wholesale marketing and terminalling segment.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	Our unfulfilled performance obligations as of June 30, 2018 were as follows (in millions): Remainder of 2018 $ 87,828 2019 164,646 2020 164,295 2021 153,541 2022 and thereafter 635,164 Total expected revenue on remaining performance obligations $ 1,205,474

Net Income Per Unit (Tables)

Net Income Per Unit (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Summary of Cash Distributions	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 expected date of distribution for the distributions earned during the period ended June 30, 2018 is August 13, 2018 . The calculation of net income per unit is as follows (dollars in thousands, except units and per unit amounts): Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 Net income attributable to partners $ 25,582 $ 18,977 $ 45,577 $ 33,572 Less: General partner's distribution (including IDRs) (1) 6,200 4,608 11,910 8,845 Less: Limited partners' distribution 18,784 17,175 37,071 33,962 Earnings in excess (deficit) of distributions $ 598 $ (2,806 ) $ (3,404 ) $ (9,235 ) General partner's earnings: Distributions (including IDRs) (1) $ 6,200 $ 4,608 $ 11,910 $ 8,845 Allocation of earnings in excess (deficit) of distributions 12 (56 ) (68 ) (184 ) Total general partner's earnings $ 6,212 $ 4,552 $ 11,842 $ 8,661 Limited partners' earnings on common units: Distributions $ 18,784 $ 17,175 $ 37,071 $ 33,962 Allocation of earnings in excess (deficit) of distributions 586 (2,750 ) (3,336 ) (9,051 ) Total limited partners' earnings on common units $ 19,370 $ 14,425 $ 33,735 $ 24,911 Weighted average limited partner units outstanding (2) : Common units - (basic) 24,386,031 24,335,338 24,384,341 24,331,991 Common units - (diluted) 24,394,103 24,375,946 24,391,760 24,371,540 Net income per limited partner unit (2) : Common units - (basic) $ 0.79 $ 0.59 $ 1.38 $ 1.02 Common units - (diluted) $ 0.79 $ 0.59 $ 1.38 $ 1.02 (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 9 for further discussion related to IDRs. (2) We base our calculation of net income per unit on the weighted-average number of common limited partner units outstanding during the period.

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Summary of Changes in Carrying Amount of Equity	The summarized changes in the carrying amount of our equity from December 31, 2017 through June 30, 2018 are as follows (in thousands): Common - Public Common - Delek General Partner Total Balance at December 31, 2017 $ 174,378 $ (197,206 ) $ (6,397 ) $ (29,225 ) Distributions to unitholders and general partner related to Big Spring Logistic Assets Acquisition — (96,822 ) (1,976 ) (98,798 ) Cash distributions (1) (13,463 ) (22,558 ) (10,810 ) (46,831 ) Net income attributable to partners 12,581 21,154 11,842 45,577 Unit-based compensation 111 185 6 302 Other — — 13 13 Balance at June 30, 2018 $ 173,607 $ (295,247 ) $ (7,322 ) $ (128,962 )
Summary of Allocation of General Partner's Interest in Net Income	The following table presents the allocation of the general partner's interest in net income (in thousands, except percentage of ownership interest): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Net income attributable to partners $ 25,582 $ 18,977 $ 45,577 $ 33,572 Less: General partner's IDRs (5,817 ) (4,258 ) (11,154 ) (8,153 ) Net income available to partners $ 19,765 $ 14,719 $ 34,423 $ 25,419 General partner's ownership interest 2.0 % 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income $ 395 $ 294 $ 688 $ 508 General partner's IDRs 5,817 4,258 11,154 8,153 Total general partner's interest in net income $ 6,212 $ 4,552 $ 11,842 $ 8,661
Summary of Percentage Allocations of Available Cash From Operating Surplus	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and our unitholders in any available cash from operating surplus that we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that (i) our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and (ii) our general partner has not transferred its IDRs. Target Quarterly Distribution per Unit Marginal Percentage Interest in Distributions Target Amount Unitholders General Partner Minimum Quarterly Distribution $ 0.37500 98.0 % 2.0 % First Target Distribution above $ 0.37500 98.0 % 2.0 % up to $ 0.43125 Second Target Distribution above $ 0.43125 85.0 % 15.0 % up to $ 0.46875 Third Target Distribution above $ 0.46875 75.0 % 25.0 % up to $ 0.56250 Thereafter thereafter $ 0.56250 50.0 % 50.0 %
Summary of Distributions	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 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 (1) August 3, 2018 (1) Expected date of distribution. The allocation of total quarterly cash distributions expected to be made on August 13, 2018 to general and limited partners for the three and six months ended June 30, 2018 and the allocation of total quarterly cash distributions for the three and six months ended June 30, 2017 are 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): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 General partner's distributions: General partner's distributions $ 383 $ 350 $ 756 $ 692 General partner's IDRs 5,817 4,258 11,154 8,153 Total general partner's distributions 6,200 4,608 11,910 8,845 Limited partners' distributions: Common limited partners' distributions 18,784 17,175 37,071 33,962 Total cash distributions $ 24,984 $ 21,783 $ 48,981 $ 42,807 Cash distributions per limited partner unit $ 0.770 $ 0.705 $ 1.520 $ 1.395

Equity Method Investments (Tabl

Equity Method Investments (Tables)	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Summary of Financial Information for Equity Method Investees	Combined summarized financial information for our equity method investees is shown below (in thousands): June 30, 2018 December 31, 2017 Current assets $ 18,195 $ 12,671 Non-current assets $ 241,564 $ 244,329 Current liabilities $ 3,876 $ 1,798 Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 Revenues $ 9,886 $ 7,022 $ 17,876 $ 12,693 Gross profit $ 9,886 $ 7,022 $ 17,876 $ 12,693 Net income $ 4,800 $ 3,379 $ 7,512 $ 4,392

Segment Data (Tables)

Segment Data (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Summary Segment Data	The following is a summary of business segment operating performance as measured by contribution margin for the periods indicated (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 Pipelines and Transportation Net revenues: Affiliates $ 34,030 $ 27,668 $ 63,492 $ 54,168 Third party 3,714 2,555 7,965 4,732 Total pipelines and transportation 37,744 30,223 71,457 58,900 Operating costs and expenses: Cost of goods sold 5,195 4,403 9,636 8,808 Operating expenses 9,933 7,933 19,555 16,088 Segment contribution margin $ 22,616 $ 17,887 $ 42,266 $ 34,004 Capital spending (1) $ 826 $ 1,660 $ 2,234 $ 3,797 Wholesale Marketing and Terminalling Net revenues: Affiliates (2) $ 19,050 $ 12,156 $ 51,232 $ 22,275 Third party 109,486 84,390 211,512 175,067 Total wholesale marketing and terminalling 128,536 96,546 262,744 197,342 Operating costs and expenses: Cost of goods sold 100,821 80,636 215,412 168,821 Operating expenses 4,984 2,033 7,939 4,236 Segment contribution margin $ 22,731 $ 13,877 $ 39,393 $ 24,285 Capital spending (1) $ 1,426 $ 459 $ 2,215 $ 1,113 Consolidated Net revenues: Affiliates $ 53,080 $ 39,824 $ 114,724 $ 76,443 Third party 113,200 86,945 219,477 179,799 Total consolidated 166,280 126,769 334,201 256,242 Operating costs and expenses: Cost of goods sold 106,016 85,039 225,048 177,629 Operating expenses 14,917 9,966 27,494 20,324 Contribution margin 45,347 31,764 81,659 58,289 General and administrative expenses 3,747 2,656 6,722 5,504 Depreciation and amortization 7,019 5,742 13,019 10,935 Loss (gain) on asset disposals (129 ) (5 ) (69 ) 7 Operating income $ 34,710 $ 23,371 $ 61,987 $ 41,843 Capital spending (1) $ 2,252 $ 2,119 $ 4,449 $ 4,910 (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 six months ended June 30, 2018 . No costs were capitalized during the three months ended June 30, 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 June 30, 2018 and December 31, 2017 (in thousands): June 30, 2018 December 31, 2017 Pipelines and transportation $ 439,311 $ 349,351 Wholesale marketing and terminalling 211,038 94,179 Total assets $ 650,349 $ 443,530 Property, plant and equipment and accumulated depreciation as of June 30, 2018 and depreciation expense by reporting segment for the three and six months ended June 30, 2018 were as follows (in thousands): Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 362,128 $ 84,833 $ 446,961 Less: accumulated depreciation (96,915 ) (30,713 ) (127,628 ) Property, plant and equipment, net $ 265,213 $ 54,120 $ 319,333 Depreciation expense for the three months ended June 30, 2018 $ 5,594 $ 1,336 $ 6,930 Depreciation expense for the six months ended June 30, 2018 $ 10,524 $ 2,406 $ 12,930

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Summary of Fair Value Hierarchy for Financial Assets	The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis at June 30, 2018 and December 31, 2017 was as follows (in thousands): As of June 30, 2018 Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ — $ 2 $ — $ 2 Total assets — 2 — 2 Liabilities Commodity derivatives — (380 ) — (380 ) Net liabilities $ — $ (378 ) $ — $ (378 ) 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)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of the Fair Value of Derivative Instruments	The following table presents the fair value of our derivative instruments as of June 30, 2018 and December 31, 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 condensed consolidated balance sheets. During the three and six months ended June 30, 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 condensed consolidated statements of income and comprehensive income. See Note 13 for further information regarding the fair value of derivative instruments. (in thousands) June 30, 2018 December 31, 2017 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives: Commodity derivatives (1) Accrued expenses and other current liabilities $ 2 $ (380 ) $ — $ (1,087 ) Total gross fair value of derivatives 2 (380 ) — (1,087 ) Less: Counterparty netting and cash collateral (deficit) (2) (88 ) (380 ) — (290 ) Total net fair value of derivatives $ 90 $ — $ — $ (797 ) (1) As of June 30, 2018 and December 31, 2017 , we had open derivative contracts representing 117,000 barrels and 370,000 barrels, respectively, of refined petroleum products. (2) As of June 30, 2018 and December 31, 2017 , we had cash collateral of $0.5 million and $0.3 million , respectively, netted with the net derivative position of our counterparty.
Summary of Recognized Gains (Losses) Associated with Derivatives	Recognized gains (losses) associated with our derivatives for the three and six months ended June 30, 2018 and 2017 were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, Derivative Type Income Statement Location 2018 2017 2018 2017 Commodity derivatives Cost of goods sold $ (843 ) $ 606 $ 740 $ 1,116

Organization and Basis of Pre32

Organization and Basis of Presentation Organization and Basis of Presentation (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Distributions from equity method investments	$ 660	$ 501

Acquisitions - Narrative (Deta

Acquisitions - Narrative (Details) $ in Thousands	Mar. 01, 2018USD ($)storage_tankunderground_saltwell	Jun. 30, 2018USD ($)	Dec. 31, 2017USD ($)
Schedule of Asset Acquisitions, by Acquisition [Line Items]
Intangible assets, net		$ 157,643	$ 15,917
Big Spring Pipeline
Schedule of Asset Acquisitions, by Acquisition [Line Items]
Consideration transferred	$ 170,800
Number of storage tanks | storage_tank	75
Number of underground saltwells | underground_saltwell	4
Excess cash paid over book value	$ 98,800
Assets	72,000
Asset retirement obligations	800
Business Acquisition, Transaction Costs	400
Intangible assets, net	$ 144,200
Finite-lived intangible amortization period	20 years

Related Party Transactions - Co

Related Party Transactions - Commercial Agreements (Details)		Mar. 01, 2018USD ($)bbl / pure$ / bbl	Jun. 30, 2018USD ($)$ / bbl
Related Party Transaction [Line Items]
Term of agreement, extension			5 years
Crude Oil Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate	[1]	0.05
Crude Oil and Refined Products Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate	[1]	0.05
Minimum throughput commitment		104,300
Rail Offloading
Related Party Transaction [Line Items]
Throughput commitment tariff rate	[1]	0.40
Minimum throughput commitment		4,500
Terminalling
Related Party Transaction [Line Items]
Throughput commitment tariff rate	[1]	0.66
Minimum throughput commitment		29,250
Dedicated Asphalt Terminalling
Related Party Transaction [Line Items]
Throughput commitment tariff rate	[1]	8.30
Storage, Throughput Facilities
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $	[1]	$ 1,374,630
Storage Asphalt Services
Related Party Transaction [Line Items]
Minimum monthly storage fee revenue, amount | $	[1]	$ 456,490
Marketing Services
Related Party Transaction [Line Items]
Minimum throughput commitment		65,000
Maximum
Related Party Transaction [Line Items]
Term of agreement		10 years
Maximum | Crude Oil Throughput
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Maximum | Crude Oil and Refined Products Throughput
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Maximum | Rail Offloading
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Maximum | Dedicated Asphalt Terminalling
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Minimum throughput commitment		2,380
Maximum | Storage, Throughput Facilities
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Maximum | Storage Asphalt Services
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Maximum | Marketing Services
Related Party Transaction [Line Items]
Term of agreement	[2]	15 years
Throughput commitment tariff rate	[1]	0.71
Minimum
Related Party Transaction [Line Items]
Term of agreement		5 years
Minimum | Crude Oil Throughput
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum | Crude Oil and Refined Products Throughput
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum | Rail Offloading
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum | Dedicated Asphalt Terminalling
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum throughput commitment		1,020
Minimum | Storage, Throughput Facilities
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum | Storage Asphalt Services
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Minimum | Marketing Services
Related Party Transaction [Line Items]
Term of agreement	[2]	10 years
Throughput commitment tariff rate	[1]	0.50
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Crude Oil Throughput
Related Party Transaction [Line Items]
Term of agreement			10 years
Term of agreement, extension			5 years
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Maximum | Crude Oil Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate			0.66
Big Spring Pipeline, Storage And Throughput Facilities Agreement | Minimum | Crude Oil Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate			0.05
Big Spring Asphalt Services Agreement
Related Party Transaction [Line Items]
Term of agreement			10 years
Term of agreement, extension			5 years
Big Spring Asphalt Services Agreement | Storage, Throughput Facilities
Related Party Transaction [Line Items]
Throughput commitment tariff rate			8.30
Big Spring Marketing Agreement
Related Party Transaction [Line Items]
Term of agreement			10 years
Term of agreement, extension			5 years
Big Spring Marketing Agreement | Maximum | Crude Oil Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate			0.71
Big Spring Marketing Agreement | Minimum | Crude Oil Throughput
Related Party Transaction [Line Items]
Throughput commitment tariff rate			0.50
Omnibus Agreement | Delek US and affiliates
Related Party Transaction [Line Items]
Related party annual service fee | $			$ 3,900,000
[1]	Fees payable to the Partnership by Delek.
[2]	Maximum term gives effect to the extension by (i) the Partnership of the Pipelines, Storage and Throughput Facilities Agreement and Asphalt Services Agreement pursuant to the terms thereof and (ii) Delek of the Marketing Agreement pursuant to the terms thereof. Maximum term excludes the impact of the automatic annual renewal of these agreements, unless terminated by either party, subsequent to the extension.

Related Party Transactions - O

Related Party Transactions - Omnibus Agreement (Details) - USD ($) $ in Thousands	May 07, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	May 31, 2018	Feb. 28, 2018	Feb. 28, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,000			$ 20,500
Reimbursement of capital expenditures by Delek											$ 2,700	$ 3,835
Accrual for environmental loss contingencies, period increase (decrease)										$ 300	100	400
Delek US and affiliates
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid					$ 14,700	$ 17,200	$ 16,200	$ 14,200
Omnibus Agreement | Delek US | Delek US and affiliates | Operating and maintenance expense
Related Party Transaction [Line Items]
Reimbursement for costs incurred for asset failures											7,800
Omnibus Agreement | Delek US | Delek US and affiliates | Other long term liabilities
Related Party Transaction [Line Items]
Reimbursement of capital expenditures by Delek									$ 400	$ 800	$ 2,700	$ 3,800

Related Party Transactions - S

Related Party Transactions - Summary of Transactions (Details) - USD ($) $ in Thousands	May 07, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	May 31, 2018	Feb. 28, 2018	Feb. 28, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,000			$ 20,500
Affiliates									$ 53,080	$ 39,824	$ 114,724	$ 76,443
Delek US and affiliates
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party									53,080	39,824
Distribution Made to Limited Partner, Cash Distributions Paid					$ 14,700	$ 17,200	$ 16,200	$ 14,200
Affiliates											114,724	76,443
General and administrative expenses									2,505	1,561	3,462	3,254
Cost of goods sold | Delek US and affiliates
Related Party Transaction [Line Items]
Expenses									99,515	8,252	181,715	17,180
Operating and maintenance expense | Delek US and affiliates
Related Party Transaction [Line Items]
Expenses									$ 11,422	$ 6,385	18,911	$ 13,481
Delek US | Omnibus Agreement | Operating and maintenance expense | Delek US and affiliates
Related Party Transaction [Line Items]
Reimbursement for costs incurred for asset failures											$ 7,800

Related Party Transactions - Q

Related Party Transactions - Quarterly Cash Distributions (Details) - USD ($) $ in Thousands	Aug. 13, 2018	Jul. 24, 2018	May 07, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	May 31, 2018	Feb. 28, 2018	Feb. 28, 2017
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid			$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,000			$ 20,500
Subsequent Event
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 24,984
Delek US and affiliates
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid							$ 14,700	$ 17,200	$ 16,200	$ 14,200
Delek US and affiliates | Subsequent Event
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared		$ 18,000

Revenues (Details)

Revenues (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Total revenue		$ 166,280	$ 126,769	$ 334,201	$ 256,242
Amortization of other deferred charges				2,404	0
Service Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		4,207		8,767
Service Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue	[1]	37,741		67,204
Product Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		108,993		210,710
Product Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		794		21,028
Lease Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		14,545		26,492
Pipelines and transportation
Disaggregation of Revenue [Line Items]
Total revenue		37,744	30,223	71,457	58,900
Pipelines and transportation | Service Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		3,714		7,965
Pipelines and transportation | Service Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue	[1]	23,160		43,057
Pipelines and transportation | Product Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		0		0
Pipelines and transportation | Product Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		0		0
Pipelines and transportation | Lease Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		10,870		20,435
Wholesale marketing and terminalling
Disaggregation of Revenue [Line Items]
Total revenue		128,536	$ 96,546	262,744	$ 197,342
Wholesale marketing and terminalling | Service Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		493		802
Wholesale marketing and terminalling | Service Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue	[1]	14,581		24,147
Wholesale marketing and terminalling | Product Revenue - Third Party
Disaggregation of Revenue [Line Items]
Total revenue		108,993		210,710
Wholesale marketing and terminalling | Product Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		794		21,028
Wholesale marketing and terminalling | Lease Revenue - Affiliate
Disaggregation of Revenue [Line Items]
Total revenue		$ 3,675		$ 6,057
[1]	Net of $1.8 million and $2.4 million of amortization expense for the three and six months ended, respectively, related to a customer contract intangible asset recorded in the wholesale marketing and terminalling segment.

Revenues - Remaining Performanc

Revenues - Remaining Performance Obligation Expected Timing of Satisfaction - Period (Details) $ in Thousands	Jun. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 87,828
Revenue, remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 164,646
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, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 164,295
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, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 153,541
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, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,205,474
Revenue, remaining performance obligation, expected timing of satisfaction

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventories	$ 12,715	$ 20,855

Long-Term Obligations - Second

Long-Term Obligations - Second Amended and Restated Credit Agreement (Details) - Line of Credit - Revolving Credit Facility - Fifth Third Bank - USD ($)	Dec. 30, 2014	Jun. 30, 2018
Line of Credit Facility [Line Items]
Weighted average interest rate (as percent)		4.90%
Prime Rate | United States of America, Dollars
Line of Credit Facility [Line Items]
Variable rate description	U.S. dollar prime rate
London Interbank Offered Rate (LIBOR) | United States of America, Dollars
Line of Credit Facility [Line Items]
Variable rate description	LIBOR
Canadian prime rate | Canada, Dollars
Line of Credit Facility [Line Items]
Variable rate description	Canadian dollar prime rate
Canadian Dealer Offered Rate (CDOR) | Canada, Dollars
Line of Credit Facility [Line Items]
Variable rate description	Canadian Dealer Offered Rate
Second Amended and Restated Credit Agreement
Line of Credit Facility [Line Items]
Maximum lender commitment	$ 700,000,000
Maximum amount under accordion feature	$ 800,000,000
Commitment fee (as percent)		0.50%
Principal amount of Holdings Note		$ 102,000,000
Outstanding borrowings		493,900,000
Letters of credit outstanding		0
Unused credit commitment		$ 206,100,000

Long-Term Obligations - 6.75%

Long-Term Obligations - 6.75% Senior Notes Due 2025 (Details) - Senior Notes - Senior 2025 Notes - USD ($)	May 23, 2017	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Face amount of debt	$ 250,000,000
Interest rate (as percent)	6.75%
Purchase price (as percent)		101.00%
Long-term Line of Credit		$ 250,000,000
Deferred financing costs		5,100,000	$ 5,500,000
Debt discount		$ 1,600,000	$ 1,700,000
Anytime prior to May 15, 2020
Debt Instrument [Line Items]
Redemption price, percentage of principal amount redeemed (as percent)	35.00%
Redemption price (as percent)	106.75%
Twelve-month period beginning on May 15, 2020
Debt Instrument [Line Items]
Redemption price (as percent)	105.063%
Twelve-month period beginning on May 15, 2021
Debt Instrument [Line Items]
Redemption price (as percent)	103.375%
Twelve-month period beginning on May 15, 2022
Debt Instrument [Line Items]
Redemption price (as percent)	101.688%
Beginning on May 15, 2023 and thereafter
Debt Instrument [Line Items]
Redemption price (as percent)	100.00%

Net Income Per Unit - Narrativ

Net Income Per Unit - Narrative (Details) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Earnings Per Share [Abstract]
General partner's ownership interest (as percent)	2.00%	2.00%	2.00%	2.00%
Quarterly distributions of available cash, minimum level (in dollars per share)			0.43125

Net Income Per Unit (Details)

Net Income Per Unit (Details) $ / shares in Units, $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2018USD ($)$ / sharesshares	Jun. 30, 2017USD ($)$ / sharesshares	Jun. 30, 2018USD ($)$ / sharesshares	Jun. 30, 2017USD ($)$ / sharesshares
Net Income Per Unit [Line Items]
Net income attributable to partners		$ 25,582	$ 18,977	$ 45,577	$ 33,572
Less: Partners' distribution		18,784	17,175	37,071	33,962
Allocation of earnings in excess (deficit) of distributions		$ 598	$ (2,806)	$ (3,404)	$ (9,235)
Footnote [Abstract]
General partner's ownership interest (as percent)		2.00%	2.00%	2.00%	2.00%
Quarterly distributions of available cash, minimum level (in dollars per share) | $ / shares				0.43125
Common Units
Net Income Per Unit [Line Items]
Common units - (basic) (in shares) | shares		24,386,031	24,335,338	24,384,341	24,331,991
Common units - (diluted) (in shares) | shares		24,394,103	24,375,946	24,391,760	24,371,540
Common units - (basic) (in dollars per share) | $ / shares		$ 0.79	$ 0.59	$ 1.38	$ 1.02
Common units - (diluted) (in dollars per share) | $ / shares		$ 0.79	$ 0.59	$ 1.38	$ 1.02
General Partner
Net Income Per Unit [Line Items]
Net income attributable to partners				$ 11,842
Less: General partner's distribution (including IDRs)	[1]	$ 6,200	$ 4,608	11,910	$ 8,845
Allocation of earnings in excess (deficit) of distributions		12	(56)	(68)	(184)
Total partner's earnings		6,212	4,552	11,842	8,661
Common unitholders | Common Units
Net Income Per Unit [Line Items]
Less: Partners' distribution		18,784	17,175	37,071	33,962
Allocation of earnings in excess (deficit) of distributions		586	(2,750)	(3,336)	(9,051)
Total partner's earnings		$ 19,370	$ 14,425	$ 33,735	$ 24,911
Common units - (basic) (in shares) | shares	[2]	24,386,031	24,335,338	24,384,341	24,331,991
Common units - (diluted) (in shares) | shares	[2]	24,394,103	24,375,946	24,391,760	24,371,540
Common units - (basic) (in dollars per share) | $ / shares	[2]	$ 0.79	$ 0.59	$ 1.38	$ 1.02
Common units - (diluted) (in dollars per share) | $ / shares	[2]	$ 0.79	$ 0.59	$ 1.38	$ 1.02
[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 9 for further discussion related to IDRs.
[2]	Fees payable to the Partnership by Delek.

Equity - Narrative (Details)

Equity - Narrative (Details) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Class of Stock [Line Items]
Delek's limited partner ownership interest (as percent)			61.40%
General partner's ownership interest (as percent)	2.00%	2.00%	2.00%	2.00%
General partner units outstanding (units)	497,861		497,861		497,604
Delek US
Class of Stock [Line Items]
Ownership Interest in General Partner (as percent)	94.60%		94.60%
Affiliates
Class of Stock [Line Items]
Ownership Interest in General Partner (as percent)	5.40%		5.40%
Common unitholders - public
Class of Stock [Line Items]
Common units outstanding (in shares)	9,101,137		9,101,137		9,088,587
Common unitholders - Delek
Class of Stock [Line Items]
Common units outstanding (in shares)	15,294,046		15,294,046		15,294,046

Equity - Equity Activity (Deta

Equity - Equity Activity (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2017				24,880,237
General partner units issued to maintain 2% interest				257
Unit-based compensation awards (1)	[1]			12,550
Balance at June 30, 2018		24,893,044		24,893,044
Partners' Capital Account, Units Withheld for Taxes				598
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance at December 31, 2017				$ (29,225)
Allocation Of Net Sponsor Investment To Unitholders				(98,798)
Cash distributions (1)	[2]			(46,831)
Net income attributable to partners		$ 25,582	$ 18,977	45,577	$ 33,572
Unit-based compensation				302
Other				13
Balance at June 30, 2018		$ (128,962)		$ (128,962)
Limited Partner | Common unitholders - public
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2017				9,088,587
General partner units issued to maintain 2% interest				0
Unit-based compensation awards (1)	[1]			12,550
Balance at June 30, 2018		9,101,137		9,101,137
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance at December 31, 2017				$ 174,378
Allocation Of Net Sponsor Investment To Unitholders				0
Cash distributions (1)	[2]			(13,463)
Net income attributable to partners				12,581
Unit-based compensation				111
Other				0
Balance at June 30, 2018		$ 173,607		$ 173,607
Limited Partner | Common unitholders - Delek
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2017				15,294,046
General partner units issued to maintain 2% interest				0
Unit-based compensation awards (1)	[1]			0
Balance at June 30, 2018		15,294,046		15,294,046
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance at December 31, 2017				$ (197,206)
Allocation Of Net Sponsor Investment To Unitholders				(96,822)
Cash distributions (1)	[2]			(22,558)
Net income attributable to partners				21,154
Unit-based compensation				185
Other				0
Balance at June 30, 2018		$ (295,247)		(295,247)
Limited Partner | Vested Phantom Units
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cash distributions (1)				$ 100
General Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2017				497,604
General partner units issued to maintain 2% interest				257
Unit-based compensation awards (1)	[1]			0
Balance at June 30, 2018		497,861		497,861
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance at December 31, 2017				$ (6,397)
Allocation Of Net Sponsor Investment To Unitholders				(1,976)
Cash distributions (1)	[2]			(10,810)
Net income attributable to partners				11,842
Unit-based compensation				6
Other				13
Balance at June 30, 2018		$ (7,322)		$ (7,322)
[1]	(1) Unit-based compensation awards are presented net of 598 units withheld for taxes.
[2]	(1) Cash distributions include $0.1 million related to distribution equivalents on vested phantom units.

Equity - Allocations of Net In

Equity - Allocations of Net Income (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Equity [Abstract]
Net income attributable to partners	$ 25,582	$ 18,977	$ 45,577	$ 33,572
Less: General partner's IDRs	(5,817)	(4,258)	(11,154)	(8,153)
Net income available to partners	$ 19,765	$ 14,719	$ 34,423	$ 25,419
General partner's ownership interest (as percent)	2.00%	2.00%	2.00%	2.00%
General partner's allocated interest in net income	$ 395	$ 294	$ 688	$ 508
General partner's IDRs	5,817	4,258	11,154	8,153
Total general partner's interest in net income	$ 6,212	$ 4,552	$ 11,842	$ 8,661

Equity - Incentive Distributio

Equity - Incentive Distribution Rights (Details) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Equity [Abstract]
General partner's ownership interest (as percent)	2.00%	2.00%	2.00%	2.00%
Minimum quarterly distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.37500
Minimum quarterly distribution | Common unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			98.00%
Minimum quarterly distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			2.00%
First target distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.37500
First target distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.43125
First target distribution | Common unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			98.00%
First target distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			2.00%
Second target distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.43125
Second target distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.46875
Second target distribution | Common unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			85.00%
Second target distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			15.00%
Third target distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.46875
Third target distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.56250
Third target distribution | Common unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			75.00%
Third target distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			25.00%
Thereafter
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Target Quarterly Distribution per Unit (in dollars per share)			$ 0.56250
Thereafter | Common unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			50.00%
Thereafter | General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions (as percent)			50.00%

Equity - Cash Distributions (D

Equity - Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 13, 2018	May 07, 2018	Feb. 12, 2018	Nov. 14, 2017	Aug. 11, 2017	May 12, 2017	Feb. 28, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Distribution Made to Limited Partner [Line Items]
Total Quarterly Distribution Per Limited Partner Unit - Paid (in dollars per share)		$ 0.75	$ 0.725	$ 0.715	$ 0.705
Total Quarterly Distribution Per Limited Partner Unit, Annualized - Paid (in dollars per share)		$ 3	$ 2.90	$ 2.86	$ 2.82
Total Cash Distribution, including general partner interest and IDRs		$ 23,997	$ 22,777	$ 22,270	$ 21,783	$ 21,000	$ 20,500
Total Quarterly Distribution Per Limited Partner Unit - Declared (in dollars per share)								$ 0.770	$ 0.705	$ 1.52	$ 1.3950
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Total Cash Distribution, including general partner interest and IDRs	$ 24,984
Total Quarterly Distribution Per Limited Partner Unit - Declared (in dollars per share)	$ 0.770
Distribution Made To Limited Partner Distributions Declared Annualized Per Unit	$ 3.08

Equity - Distributions Earned

Equity - Distributions Earned (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Distributions Earned by Limited or General Partners [Line Items]
General partner's distributions	$ 383	$ 350
General partner's IDRs	5,817	4,258	$ 11,154	$ 8,153
Total general partner's distributions	6,200	4,608	11,910	8,845
Common limited partners' distributions	18,784	17,175	37,071	33,962
Total cash distributions	$ 24,984	$ 21,783	$ 48,981	$ 42,807
Cash distributions per limited partner unit (in dollars per share)	$ 0.770	$ 0.705	$ 1.52	$ 1.3950
General Partner
Distributions Earned by Limited or General Partners [Line Items]
General partner's distributions			$ 756	$ 692
General partner's IDRs			$ 11,154	$ 8,153

Equity Based Compensation (Det

Equity Based Compensation (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Total unrecognized compensation costs	$ 0.6		$ 0.6
Weighted average period of recognition (years)			10 months 15 days
Minimum
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Award vesting period (years)			1 year
Maximum
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Award vesting period (years)			5 years
General and administrative expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Unit-based compensation expense	$ 0.2	$ 0.2	$ 0.3	$ 0.4

Equity Method Investments (Det

Equity Method Investments (Details) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Feb. 28, 2018terminal	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)joint_venture	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Schedule of Equity Method Investments [Line Items]
Equity method investments, number of joint ventures | joint_venture				2
Investment in joint ventures		$ 106,432		$ 106,432		$ 106,465
CP LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest (as percent)		50.00%		50.00%
Rangeland Rio
Schedule of Equity Method Investments [Line Items]
Ownership interest (as percent)		33.00%		33.00%
Joint Ventures
Schedule of Equity Method Investments [Line Items]
Current assets		$ 18,195		$ 18,195		12,671
Non-current assets		241,564		241,564		244,329
Current liabilities		3,876		3,876		$ 1,798
Revenues		9,886	$ 7,022	17,876	$ 12,693
Gross profit		9,886	7,022	17,876	12,693
Net income		$ 4,800	$ 3,379	$ 7,512	$ 4,392
DKGP Energy Terminals, LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest (as percent)	50.00%
Equity method investment, number of terminals acquired | terminal	2

Segment Data - Narrative (Detai

Segment Data - Narrative (Details)	6 Months Ended
	Jun. 30, 2018segment
Segment Reporting [Abstract]
Number of reportable segments	2

Segment Data (Details)

Segment Data (Details) - USD ($) $ in Thousands		3 Months Ended			6 Months Ended
		Jun. 30, 2018		Jun. 30, 2017	Jun. 30, 2018		Jun. 30, 2017	Mar. 01, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Affiliates		$ 53,080		$ 39,824	$ 114,724		$ 76,443
Third party		113,200		86,945	219,477		179,799
Total revenue		166,280		126,769	334,201		256,242
Cost of Goods and Services Sold		106,016		85,039	225,048		177,629
Operating costs and expenses:
Operating expenses		14,917		9,966	27,494		20,324
Segment contribution margin		45,347		31,764	81,659		58,289
General and administrative expenses		3,747		2,656	6,722		5,504
Depreciation and amortization		7,019		5,742	13,019		10,935
Loss (gain) on asset disposals		(129)		(5)	(69)		7
Operating income		34,710		23,371	61,987		41,843
Capital spending (1)	[1]	2,252		2,119	4,449		4,910
Total assets		650,349			650,349				$ 443,530
Pipelines and transportation
Segment Reporting Information [Line Items]
Affiliates		34,030		27,668	63,492		54,168
Third party		3,714		2,555	7,965		4,732
Total revenue		37,744		30,223	71,457		58,900
Cost of Goods and Services Sold		5,195		4,403	9,636		8,808
Operating costs and expenses:
Operating expenses		9,933		7,933	19,555		16,088
Segment contribution margin		22,616		17,887	42,266		34,004
Capital spending (1)		826	[1]	1,660	2,234	[1]	3,797
Total assets		439,311			439,311				349,351
Wholesale marketing and terminalling
Segment Reporting Information [Line Items]
Affiliates	[2]	19,050		12,156	51,232		22,275
Third party		109,486		84,390	211,512		175,067
Total revenue		128,536		96,546	262,744		197,342
Cost of Goods and Services Sold		100,821		80,636	215,412		168,821
Operating costs and expenses:
Operating expenses		4,984		2,033	7,939		4,236
Segment contribution margin		22,731		13,877	39,393		24,285
Capital spending (1)		1,426	[2]	$ 459	2,215	[2]	$ 1,113
Total assets		$ 211,038			$ 211,038				$ 94,179
Big Spring Pipeline
Segment Reporting Information [Line Items]
Business Acquisition, Transaction Costs								$ 400
[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 six months ended June 30, 2018. No costs were capitalized during the three months ended June 30, 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.

Segment Data - PP&E (Details)

Segment Data - PP&E (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Property, plant and equipment	$ 446,961	$ 446,961	$ 367,179
Less: accumulated depreciation	(127,628)	(127,628)	(112,111)
Property, plant and equipment, net	319,333	319,333	$ 255,068
Depreciation expense	6,930	12,930
Pipelines and transportation
Segment Reporting Information [Line Items]
Property, plant and equipment	362,128	362,128
Less: accumulated depreciation	(96,915)	(96,915)
Property, plant and equipment, net	265,213	265,213
Depreciation expense	5,594	10,524
Wholesale marketing and terminalling
Segment Reporting Information [Line Items]
Property, plant and equipment	84,833	84,833
Less: accumulated depreciation	(30,713)	(30,713)
Property, plant and equipment, net	54,120	54,120
Depreciation expense	$ 1,336	$ 2,406

Fair Value Measurements (Detai

Fair Value Measurements (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	$ 2
Net assets (liabilities)	(378)	$ (1,087)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	0
Net assets (liabilities)	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	2
Net assets (liabilities)	(378)	(1,087)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	0
Net assets (liabilities)	0	0
Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	2
Derivative Liability	(380)	(1,087)
Commodity derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0
Derivative Liability	0	0
Commodity derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	2
Derivative Liability	(380)	(1,087)
Commodity derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0
Derivative Liability	$ 0	$ 0

Fair Value Measurements - Narr

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Cash collateral		$ 0.3
Cash deficit	$ 0.5

Derivative Instruments - Narra

Derivative Instruments - Narrative (Details)	6 Months Ended
	Jun. 30, 2018
Fuel [Member] | Forward Contracts [Member]
Derivative [Line Items]
Term of contract (less than 90 days for forward fuel contracts)	90 days

Derivative Instruments - Balan

Derivative Instruments - Balance Sheet Location (Details) $ in Thousands		Jun. 30, 2018USD ($)bbl	Dec. 31, 2017USD ($)bbl
Footnote [Abstract]
Cash deficit		$ 500
Cash collateral			$ 300
Derivatives not designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Assets		2	0
Liabilities		(380)	(1,087)
Less: Counterparty netting and cash collateral (deficit), assets	[1]	(88)	0
Less: Counterparty netting and cash collateral (deficit), liabilities	[1]	(380)	(290)
Total net fair value of derivative, assets		90	0
Total net fair value of derivative, liabilities		$ 0	$ (797)
Footnote [Abstract]
Derivative open contracts (in barrels) | bbl		117,000	370,000
Derivatives not designated as hedging instrument [Member] | Commodity derivatives | Accrued expenses and other current liabilities
Derivatives, Fair Value [Line Items]
Assets	[2]	$ 2	$ 0
Liabilities	[2]	$ (380)	$ (1,087)
[1]	As of June 30, 2018 and December 31, 2017, we had cash collateral of $0.5 million and $0.3 million, respectively, netted with the net derivative position of our counterparty.
[2]	As of June 30, 2018 and December 31, 2017, we had open derivative contracts representing 117,000 barrels and 370,000 barrels, respectively, of refined petroleum products.

Derivative Instruments - Incom

Derivative Instruments - Income Statement Location (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Commodity derivatives [Member] | Cost of goods sold | Derivatives not designated as hedging instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Recognized gain (loss)	$ (843)	$ 606	$ 740	$ 1,116

Commitments and Contingencies

Commitments and Contingencies - Crude Oil Releases (Details) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Feb. 28, 2018bbl	Mar. 31, 2013bbl
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies, period increase (decrease)	$ 0.3	$ 0.1	$ 0.4
Accrual for environmental loss contingencies, expected reimbursements		7.8
SALA Gathering System February 2018 Release - First
Loss Contingencies [Line Items]
Crude oil released (in barrels) | bbl				203
Magnolia Release
Loss Contingencies [Line Items]
Crude oil released (in barrels) | bbl					5,900
Magnolia Release | Other Current Liabilities [Member] | Magnolia Release
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies		$ 1

Commitments and Contingencies62

Commitments and Contingencies - Letters of Credit (Details)	Jun. 30, 2018USD ($)
Second Amended and Restated Credit Agreement | Line of Credit | Revolving Credit Facility | Fifth Third Bank
Debt Instrument [Line Items]
Letters of credit outstanding	$ 0

Subsequent Events - Distributi

Subsequent Events - Distribution Declaration (Details) - $ / shares	Aug. 13, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Subsequent Event [Line Items]
Cash distributions per limited partner unit (in dollars per share)		$ 0.770	$ 0.705	$ 1.52	$ 1.3950
Subsequent Event
Subsequent Event [Line Items]
Cash distributions per limited partner unit (in dollars per share)	$ 0.770