Edgar Filing: Delek Logistics Partners, LP

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Accelerated filer þ

Non-accelerated filer o

Smaller reporting company o

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Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)



þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

		For the quarterly period ended June 30, 2016



o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

		For the transition period from to

Commission file number 001-35721

DELEK LOGISTICS PARTNERS, LP

(Exact name of registrant as specified in its charter)



Delaware		45-5379027
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)

7102 Commerce Way
Brentwood, Tennessee		37027
(Address of principal executive offices)		(Zip Code)

(615) 771-6701

(Registrant’s telephone number, including area code)

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ

At July 29, 2016, there were 24,302,780 common limited partner units, no subordinated limited partner units, and 495,975 general partner units outstanding.

TABLE OF CONTENTS



PART I. FINANCIAL INFORMATION

Item 1. Financial Statements	3

Condensed Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015 (Unaudited)	3

Condensed Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2016 and 2015 (Unaudited)	4

Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2016 and 2015 (Unaudited)	5

Notes to Condensed Consolidated Financial Statements (Unaudited)	6

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	24

Item 3. Quantitative and Qualitative Disclosures about Market Risk	48

Item 4. Controls and Procedures	48

PART II. OTHER INFORMATION

Item 1. Legal Proceedings	49

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	49

Item 6. Exhibits	49

Signatures	51

Exhibit Index	52

Exhibit 31.1
Exhibit 31.2
Exhibit 32.1
Exhibit 32.2
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT

Part I.

FINANCIAL INFORMATION

Item 1. Financial Statements

Delek Logistics Partners, LP

Condensed Consolidated Balance Sheets (Unaudited)



	June 30, 2016			December 31, 2015
ASSETS	(In thousands)
Current assets:
Cash and cash equivalents	$	—		$	—
Accounts receivable	17,217			35,049
Accounts receivable from related parties	1,222			—
Inventory	9,759			10,451
Other current assets	652			1,540
Total current assets	28,850			47,040
Property, plant and equipment:
Property, plant and equipment	328,211			325,647
Less: accumulated depreciation	(81,073		)	(71,799		)
Property, plant and equipment, net	247,138			253,848
Equity method investments	73,362			40,678
Goodwill	12,203			12,203
Intangible assets, net	14,951			15,482
Other non-current assets	5,267			6,037
Total assets	$	381,771		$	375,288
LIABILITIES AND DEFICIT
Current liabilities:
Accounts payable	$	5,567		$	6,850
Accounts payable to related parties	—			3,992
Excise and other taxes payable	3,513			4,871
Tank inspection liabilities	1,055			1,890
Pipeline release liabilities	1,226			1,393
Accrued expenses and other current liabilities	2,221			1,694
Total current liabilities	13,582			20,690
Non-current liabilities:
Revolving credit facility	362,550			351,600
Asset retirement obligations	3,637			3,506
Other non-current liabilities	11,259			10,510
Total non-current liabilities	377,446			365,616
Deficit:
Common unitholders - public; 9,504,264 units issued and outstanding at June 30, 2016 (9,478,273 at December 31, 2015)	198,583			198,401
Common unitholders - Delek; 14,798,516 units issued and outstanding at June 30, 2016 (2,799,258 at December 31, 2015)	(201,035		)	(280,828		)
Subordinated unitholders - Delek; 0 units issued and outstanding at June 30, 2016 (11,999,258 at December 31, 2015)	—			78,601
General partner - 495,975 units issued and outstanding at June 30, 2016 (495,445 at December 31, 2015)	(6,805		)	(7,192		)
Total deficit	(9,257		)	(11,018		)
Total liabilities and deficit	$	381,771		$	375,288

See accompanying notes to condensed consolidated financial statements

Delek Logistics Partners, LP

Condensed Consolidated Statements of Income and Comprehensive Income (Unaudited)



	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016			2015
	(In thousands, except unit and per unit data)
Net sales:
Affiliate	$	36,694	$	39,871		$	75,454		$	72,151
Third-Party	75,159		132,263			140,455			243,495
Net sales	111,853		172,134			215,909			315,646
Operating costs and expenses:
Cost of goods sold	73,101		132,494			139,854			240,901
Operating expenses	8,730		10,798			19,194			21,575
General and administrative expenses	2,698		2,982			5,611			6,391
Depreciation and amortization	4,812		4,744			9,808			9,244
Gain on asset disposals	—		(23		)	(44		)	(18		)
Total operating costs and expenses	89,341		150,995			174,423			278,093
Operating income	22,512		21,139			41,486			37,553
Interest expense, net	3,284		2,616			6,483			4,773
Loss on equity method investments	206		149			435			149
Total non-operating expenses	3,490		2,765			6,918			4,922
Income before income tax expense	19,022		18,374			34,568			32,631
Income tax expense	129		63			227			317
Net income	18,893		18,311			34,341			32,314
Less: loss attributable to the Logistics Assets Predecessor	—		—			—			(637		)
Net income attributable to partners	$	18,893	$	18,311		$	34,341		$	32,951
Comprehensive income attributable to partners	$	18,893	$	18,311		$	34,341		$	32,951

Less: General partner's interest in net income, including incentive distribution rights	2,791		1,109			5,044			1,996
Limited partners' interest in net income	$	16,102	$	17,202		$	29,297		$	30,955

Net income per limited partner unit ⁽¹⁾:
Common units - (basic)	$	0.66	$	0.71		$	1.23		$	1.28
Common units - (diluted)	$	0.66	$	0.70		$	1.22		$	1.27
Subordinated units - Delek (basic and diluted)	$	—	$	0.71		$	1.09		$	1.28

Weighted average limited partner units outstanding ⁽¹⁾:
Common units - (basic)	24,281,930		12,224,007			20,653,210			12,220,248
Common units - (diluted)	24,367,091		12,360,519			20,735,389			12,350,621
Subordinated units - Delek (basic and diluted)	—		11,999,258			3,626,149			11,999,258

Cash distributions per limited partner unit	$	0.630	$	0.550		$	1.240		$	1.080

⁽¹⁾We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflect the conversion of the subordinated units to common units on February 25, 2016. See Notes 7 and 8 for further discussion.

See accompanying notes to condensed consolidated financial statements

Delek Logistics Partners, LP

Condensed Consolidated Statements of Cash Flows (Unaudited)



	Six Months Ended June 30,
	2016			2015
Cash flows from operating activities:	(In thousands)
Net income	$	34,341		$	32,314
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	9,808			9,244
Amortization of deferred revenue	(579		)	(221		)
Amortization of deferred financing costs	730			730
Accretion of asset retirement obligations	131			124
Deferred income taxes	—			66
Loss on equity method investments	435			149
Gain on asset disposals	(44		)	(18		)
Unit-based compensation expense	233			194
Changes in assets and liabilities, net of acquisitions:
Accounts receivable	17,832			(11,131		)
Inventories and other current assets	1,580			6,291
Accounts payable and other current liabilities	(2,113		)	192
Accounts receivable/payable to related parties	(5,331		)	8,219
Non-current assets and liabilities, net	566			407
Net cash provided by operating activities	57,589			46,560
Cash flows from investing activities:
Business combinations	—			(400		)
Purchases of property, plant and equipment	(2,975		)	(13,535		)
Proceeds from sales of property, plant and equipment	175			1,183
Equity method investments	(33,119		)	(14,789		)
Net cash used in investing activities	(35,919		)	(27,541		)
Cash flows from financing activities:
Proceeds from issuance of additional units to maintain 2% General Partner interest	14			31
Distributions to general partner	(4,087		)	(1,574		)
Distributions to common unitholders - public	(11,591		)	(9,801		)
Distributions to common unitholders - Delek	(6,255		)	(2,911		)
Distributions to subordinated unitholders - Delek	(11,503		)	(12,479		)
Distributions to Delek for acquisitions	—			(61,890		)
Proceeds from revolving credit facility	157,850			203,514
Payments of revolving credit facility	(146,900		)	(138,364		)
Predecessor division equity contribution	—			115
Reimbursement of capital expenditures by Delek	802			2,603
Net cash used in financing activities	(21,670		)	(20,756		)
Net decrease in cash and cash equivalents	—			(1,737		)
Cash and cash equivalents at the beginning of the period	—			1,861
Cash and cash equivalents at the end of the period	$	—		$	124
Supplemental disclosures of cash flow information:
Cash paid during the period for:
Interest	$	5,855		$	3,863
Income taxes	$	—		$	5
Non-cash investing activities:
Equity method investments	$	—		$	3,832
Decreases in accrued capital expenditures	$	(892	)	$	—
Non-cash financing activities:
Sponsor contribution of fixed assets	$	609		$	418

See accompanying notes to condensed consolidated financial statements

Delek Logistics Partners, LP

Notes to Condensed Consolidated Financial Statements (Unaudited)

1. Organization and Basis of Presentation

As used in this report, the terms "Delek Logistics Partners, LP," the "Partnership," "we," "us," or "our" may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. References in this report to "Delek" refer collectively to Delek US Holdings, Inc. and any of its subsidiaries, other than Delek Logistics Partners, LP and its subsidiaries and its general partner (as hereinafter defined).

The Partnership is a Delaware limited partnership formed in April 2012 by Delek and its subsidiary Delek Logistics GP, LLC, our general partner (our "general partner").

On March 31, 2015, the Partnership, through its wholly owned subsidiary Delek Logistics Operating, LLC ("OpCo"), acquired from Delek two crude oil rail offloading racks, which are designed to receive up to 25,000 barrels per day (“bpd”) of light crude oil or 12,000 bpd of heavy crude oil, or any combination of the two, delivered by rail to Delek's El Dorado, Arkansas refinery (the "El Dorado Refinery"), and related ancillary assets (the “El Dorado Assets”) (such transaction, the "El Dorado Rail Offloading Racks Acquisition").

On March 31, 2015, the Partnership, through its wholly owned subsidiary Delek Marketing & Supply, LP, acquired from Delek a crude oil storage tank (the "Tyler Crude Tank") located adjacent to Delek's Tyler, Texas refinery (the "Tyler Refinery") and certain ancillary assets (collectively, with the Tyler Crude Tank, the "Tyler Assets") (such transaction, the "Tyler Crude Tank Acquisition"). The Tyler Crude Tank has approximately 350,000 barrels of shell capacity and primarily supports the Tyler Refinery. The Tyler Assets, together with the El Dorado Assets, are hereinafter collectively referred to as the "Logistics Assets."

The El Dorado Rail Offloading Racks Acquisition and the Tyler Crude Tank Acquisition are hereinafter collectively referred to as the "Acquisitions from Delek." The Acquisitions from Delek were accounted for as transfers between entities under common control. As entities under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior periods are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of the Partnership have been retrospectively adjusted to include (i) the historical results of the El Dorado Assets, as owned and operated by Delek through March 31, 2015 (the "El Dorado Assets Predecessor") and (ii) the historical results of the Tyler Assets, as owned and operated by Delek through March 31, 2015 (the "Tyler Assets Predecessor"). The El Dorado Assets Predecessor, together with the Tyler Assets Predecessor, are hereinafter collectively referred to as the "Logistics Assets Predecessor." See Note 2 for further information regarding the El Dorado Rail Offloading Racks Acquisition and the Tyler Crude Tank Acquisition.

The accompanying unaudited condensed consolidated financial statements and related notes for the three and six month period ended June 30, 2016 include the consolidated financial position, results of operations, cash flows and equity of the Logistics Assets Predecessor as appropriate. The financial statements of the Logistics Assets Predecessor have been prepared from the separate records maintained by Delek and may not necessarily be indicative of the conditions that would have existed or the results of operations if the Logistics Assets Predecessor had been operated as unaffiliated entities. For example, the Logistics Assets Predecessor did not record revenues for intercompany terminalling, throughput, storage or other services.

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, 2015 (our "Annual Report on Form 10-K"), filed with the Securities and Exchange Commission (the "SEC") on February 29, 2016. 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, 2015 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.

Certain prior period amounts have been reclassified in order to conform to the current year presentation. These reclassifications had no effect on net income or partners' equity as previously reported.

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

New Accounting Pronouncements

In June 2016, the Financial Accounting Standards Board ("FASB") issued guidance that requires organizations to use historical experience, current conditions, reasonable and supportable forecasts and forward-looking information in the measurement of all expected credit losses on financial instruments to more accurately estimate those losses. This guidance is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. Early adoption is permitted after December 15, 2018, and interim periods within those fiscal years. 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 or results of operations.

In March 2016, the FASB issued guidance that simplifies several aspects of the accounting for share-based payment award transactions, including the accounting for excess tax benefits and deficiencies, classification of awards as either equity or liabilities and classification of excess tax benefits on the statement of cash flows. This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. Early adoption is permitted for any interim or annual financial statements that have not yet been issued. 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 or results of operations.

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 position for all leases previously accounted for as operating leases. This guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. 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 position or results of operations.

In February 2015, the FASB issued guidance that amends and simplifies the requirements for consolidation and provides additional guidance to reporting entities in evaluating whether certain legal entities such as limited partnerships, limited liability corporations and securitization structures, should be consolidated. This guidance is effective for interim and annual periods beginning after December 15, 2015. We adopted this guidance on the effective date and the adoption did not have a material impact on our business, financial position or results of operations.

2. Acquisitions

Acquisitions from Delek

During the six month period ended June 30, 2015, the Partnership acquired the assets listed below from Delek:


•	the El Dorado Assets, effective March 31, 2015, for approximately $42.5 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility; and


•	the Tyler Assets, effective March 31, 2015, for approximately $19.4 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility.

Financial Results of the El Dorado Assets and the Tyler Assets

The acquisitions of the El Dorado Assets and the Tyler Assets were considered transfers of businesses between entities under common control. Accordingly, the El Dorado Rail Offloading Racks Acquisition and the Tyler Crude Tank Acquisition were recorded at amounts based on Delek's historical carrying values as of the acquisition date, which were $7.6 million and $11.6 million as of March 31, 2015, respectively. Our historical financial statements have been retrospectively adjusted to reflect the results of operations, financial position, cash flows and equity attributable to the El Dorado Assets and the Tyler Assets, as if we owned the assets for the period ended March 31, 2015. The results of the El Dorado Assets and the Tyler Assets are included in the pipelines and transportation segment.

The table below presents our results of operations, the effect of including the results of the El Dorado Assets and the Tyler Assets, and the adjusted total amounts included in our consolidated financial statements for the six months ended June 30, 2015.

Condensed Combined Statements of Operations



	Delek Logistics Partners, LP			El Dorado Assets (El Dorado Assets Predecessor)			Tyler Assets (Tyler Assets Predecessor)			Six Months Ended June 30, 2015
	(In thousands)
Net Sales	$	315,646		$	—		$	—		$	315,646
Operating costs and expenses:
Cost of goods sold	240,901			—			—			240,901
Operating expenses	21,408			167			—			21,575
General and administrative expenses	6,391			—			—			6,391
Depreciation and amortization	8,774			372			98			9,244
Gain on asset disposals	(18		)	—			—			(18		)
Total operating costs and expenses	277,456			539			98			278,093
Operating income (loss)	38,190			(539		)	(98		)	37,553
Interest expense, net	4,773			—			—			4,773
Loss on equity method investments	149			—			—			149
Total non-operating costs and expenses	4,922			—			—			4,922
Net income (loss) before income tax expense	33,268			(539		)	(98		)	32,631
Income tax expense	317			—			—			317
Net income (loss)	32,951			(539		)	(98		)	32,314
Less: loss attributable to the Logistics Assets Predecessor	—			(539		)	(98		)	(637		)
Net income attributable to partners	$	32,951		$	—		$	—		$	32,951

3. Related Party Transactions

Commercial Agreements

The Partnership has a number of 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. 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 oil pipeline index or various iterations of the consumer price index and the producer price index; provided, however, that in no event will the fees be adjusted below the amount initially set forth in the applicable agreement.

See our Annual Report on Form 10-K for a more complete description of certain of our commercial agreements and other agreements with Delek.

Omnibus Agreement. The Partnership entered into an omnibus agreement with Delek, our general partner, OpCo, Lion Oil Company and certain of the Partnership's and Delek's other subsidiaries on November 7, 2012, which was subsequently amended and restated on July 26, 2013, February 10, 2014 and March 31, 2015 in connection with our subsequent acquisitions from Delek (collectively, the "Omnibus Agreement"). The third amendment and restatement occurring on March 31, 2015 generally provided for the following: (i) revisions of the schedules to include the El Dorado Assets and the Tyler Assets, (ii) revisions of certain provisions and schedules with respect to certain environmental matters, (iii) the addition of DKL Transportation, LLC as a party to the agreement, (iv) the elimination of certain provisions under the Omnibus Agreement that had expired, and (v) updating the annual administrative fee payable by us to Delek for general corporate and administrative services that Delek and its affiliates provide to us to reflect the inflationary increase provided for under the Omnibus Agreement, from $3.3 million to $3.4 million, which is prorated and payable monthly. The Partnership entered into an amendment to the third amended and restated omnibus agreement on August 3, 2015, with an effective date of April 1, 2015 (the third amended and restated omnibus agreement between the Partnership, Delek and the general partner, as amended, is referred to as the "Third Restated Omnibus Agreement"). This amendment eliminated a $1.0 million per event deductible that applied to certain asset failures before Delek was required to reimburse the Partnership.

Pursuant to the terms of the Omnibus Agreement, we were reimbursed for certain capital expenditures in the amount of $0.6 million and $0.8 million during the three and six months ended June 30, 2016, respectively, and $1.4 million and $2.6 million during the three and six months ended June 30, 2015, respectively. These amounts are recorded in other long term liabilities and are amortized to revenue over the life of the underlying revenue agreement corresponding to the asset. Additionally, we 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 Agreement. We were reimbursed $0.1 million and $1.0 million for these matters during the three and six months ended June 30, 2016, respectively. During the three and six months ended June 30, 2015, we were reimbursed for the costs incurred in connection with an asset failure near Fouke, Arkansas and the subsequent repair of the asset pursuant to the terms of the Third Restated Omnibus Agreement.

Logistics Assets Predecessor Transactions

Related-party transactions of the Logistics Assets Predecessor were settled through division equity. Costs related specifically to us have been identified and included in the accompanying consolidated statements of income and comprehensive income. Prior to the Acquisitions from Delek, we were not allocated certain corporate costs. These costs were primarily allocated based on a percentage of salaries expense and property, plant and equipment costs. In the opinion of management, the methods for allocating these costs are reasonable. It is not practicable to estimate the costs that would have been incurred by us if the Logistics Assets Predecessor had been operated on a stand-alone basis.

Summary of Transactions

Revenues from affiliates consist primarily of revenues from gathering, transportation, storage, offloading, wholesale marketing and products terminalling services provided primarily to Delek based on regulated tariff rates or contractually based fees, as well as product sales to Alon USA Energy, Inc., an equity method investee of Delek. The Logistics Assets Predecessor did not record revenues for intercompany terminalling, throughput, storage or other services. 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 Third Restated Omnibus Agreement. Additionally, the Partnership is required to reimburse Delek for direct or allocated costs and expenses incurred by Delek on behalf of the Partnership and for charges Delek incurred for the management and operation of our logistics assets, including an annual fee for various centralized corporate services, which are included in general and administrative services. In addition to these transactions, we purchase finished products and bulk biofuels from Delek, the costs of which are included in cost of goods sold.

A summary of revenue and expense transactions with Delek and its affiliates, including expenses directly charged and allocated to our Logistics Assets Predecessor, are as follows (in thousands):



	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015

Revenues	$	36,694	$	39,871	$	75,454	$	72,151
Cost of goods sold	$	8,127	$	36,842	$	18,817	$	43,749
Operating and maintenance expenses⁽¹⁾	$	7,085	$	7,509	$	14,750	$	14,894
General and administrative expenses	$	1,608	$	1,577	$	2,954	$	2,833


⁽¹⁾	Operating and maintenance expenses include costs allocated to the Logistics Assets Predecessor for operating support provided by Delek, including certain labor related costs, property and liability insurance costs and certain other operating expenses. The costs that were allocated to us by Delek were $0.2 million for the six months ended June 30, 2015.

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 2016, we paid quarterly cash distributions, of which $10.5 million and $11.3 million, respectively, were paid to Delek and our general partner. On July 25, 2016, our general partner's board of directors declared a quarterly cash distribution totaling $18.1 million, based on the available cash as of the date of determination for the end of the second quarter of 2016, payable on August 12, 2016, of which $12.1 million is expected to be paid to Delek and our general partner, including the payment for the IDRs.

4. Inventory

Inventories consisted of $9.8 million and $10.5 million of refined petroleum products as of June 30, 2016 and December 31, 2015, respectively. Cost of inventory is stated at the lower of cost or market, with cost determined on a first-in, first-out basis.

5. Second Amended and Restated Credit Agreement

We entered into a senior secured revolving credit agreement on November 7, 2012, with Fifth Third Bank, as administrative agent, and a syndicate of lenders. The agreement was amended and restated on July 9, 2013 (the "Amended and Restated Credit Agreement") and was most recently amended and restated on December 30, 2014 (the “Second Amended and Restated Credit Agreement”). Under the terms of the Second Amended and Restated Credit Agreement, the lender commitments were increased from $400.0 million to $700.0 million. The Second Amended and Restated Credit Agreement also contains an accordion feature whereby the Partnership can increase the size of the credit facility to an aggregate of $800.0 million, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. While the majority of the terms of the Second Amended and Restated Credit Agreement are substantially unchanged from the predecessor facility, among other things, changes were made to certain negative covenants, the financial covenants and the interest rate pricing grid. The Second Amended and Restated Credit Agreement contains an option for Canadian dollar denominated borrowings.

Borrowings denominated in U.S. dollars bear interest at either a U.S. dollar prime rate, plus an applicable margin, or the London Interbank Offered Rate ("LIBOR"), plus an applicable margin, at the election of the borrowers. Borrowings denominated in Canadian dollars bear interest at either a Canadian dollar prime rate, plus an applicable margin, or the Canadian Dealer Offered Rate, plus an applicable margin, at the election of the borrowers. The applicable margin in each case varies based upon the Partnership's most recent leverage ratio calculation delivered to the lenders, as called for and defined under the terms of the credit facility. At June 30, 2016, the weighted average interest rate for our borrowings under the facility was approximately 2.8%. Additionally, the Second Amended and Restated Credit Agreement requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of June 30, 2016, this fee was 0.4% per year.

The obligations under the Second Amended and Restated Credit Agreement remain secured by first priority liens on substantially all of the Partnership's and its subsidiaries' tangible and intangible assets. Additionally, Delek Marketing & Supply, LLC ("Delek Marketing"), a direct wholly owned subsidiary of Delek, continues to provide a limited guaranty of the Partnership's obligations under the Second Amended and Restated Credit Agreement. Delek Marketing's guaranty is (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek US in favor of Delek Marketing (the "Holdings Note") and (ii) secured by Delek Marketing's pledge of the Holdings Note to our lenders under the Second Amended and Restated Credit Agreement. As of June 30, 2016, the principal amount of the Holdings Note was $102.0 million, plus unpaid interest accrued since the issuance date. The Second Amended and Restated Credit Agreement matures on December 30, 2019.

As of June 30, 2016, we had $362.6 million in outstanding borrowings under the Second Amended and Restated Credit Agreement. Additionally, we had in place letters of credit totaling $7.5 million, primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn under these letters of credit at June 30, 2016. Unused credit commitments under the Second Amended and Restated Credit Agreement as of June 30, 2016 were $329.9 million.

6. 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.

7. Net Income Per Unit

We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and IDRs. The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs, by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our Partnership Agreement, which are 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. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding.

Following the February 12, 2016 payment of the cash distribution attributable to the fourth quarter of 2015 and confirmation by the board of directors of our general partner (based on the recommendation of the Conflicts Committee) on February 25, 2016 that the requirements under the Partnership Agreement for the conversion of all subordinated units into common units were satisfied, the subordination period for such subordinated units ended. As a result, in the first quarter of 2016, each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. The conversion did not impact the amount of the cash distribution paid or the total number of the Partnership's outstanding units representing limited partner interests. The Partnership's net income was allocated to the general partner and the limited partners, including the holders of the subordinated units through February 24, 2016, in accordance with our Partnership Agreement.

Our distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below represents total cash distributions applicable to the period in which the distributions are earned. The expected date of distribution for the distributions earned during the period ended June 30, 2016 is August 12, 2016. 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,
	2016		2015		2016			2015
Net income attributable to partners	$	18,893	$	18,311	$	34,341		$	32,951
Less: General partner's distribution (including IDRs) ⁽¹⁾	2,775		1,030		5,061			1,898
Less: Limited partners' distribution	15,310		6,738		25,695			13,213
Less: Subordinated partner's distribution	—		6,600		4,424			12,959
(Distributions) earnings excess	$	808	$	3,943	$	(839	)	$	4,881

General partner's earnings:
Distributions (including IDRs) ⁽¹⁾	$	2,775	$	1,030	$	5,061		$	1,898
Allocation of (distributions) earnings excess	16		79		(17		)	98
Total general partner's earnings	$	2,791	$	1,109	$	5,044		$	1,996

Limited partners' earnings on common units:
Distributions	$	15,310	$	6,738	$	25,695		$	13,213
Allocation of (distributions) earnings excess	792		1,952		(340		)	2,416
Total limited partners' earnings on common units	$	16,102	$	8,690	$	25,355		$	15,629

Limited partners' earnings on subordinated units:
Distributions	$	—	$	6,600	$	4,424		$	12,959
Allocation of (distributions) earnings excess	—		1,912		(482		)	2,367
Total limited partner's earnings on subordinated units	$	—	$	8,512	$	3,942		$	15,326

Weighted average limited partner units outstanding ⁽³⁾:
Common units - (basic)	24,281,930		12,224,007		20,653,210			12,220,248
Common units - (diluted)	24,367,091		12,360,519		20,735,389			12,350,621
Subordinated units - Delek (basic and diluted)⁽²⁾	—		11,999,258		3,626,149			11,999,258

Net income per limited partner unit ⁽³⁾:
Common units - (basic)	$	0.66	$	0.71	$	1.23		$	1.28
Common units - (diluted)	$	0.66	$	0.70	$	1.22		$	1.27
Subordinated units - Delek (basic and diluted)	$	—	$	0.71	$	1.09		$	1.28

⁽¹⁾General partner distributions (including IDRs) consist of the payment with respect to the 2% general partner interest and payment on the 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 8 for further discussion related to IDRs.

⁽²⁾ On February 25, 2016, each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. Distributions and the Partnership's net income were allocated to the subordinated units through February 24, 2016.

⁽³⁾ We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflect the conversion of the subordinated units to common units on February 25, 2016.

8. Equity

We had 9,504,264 common limited partner units held by the public outstanding as of June 30, 2016. Additionally, as of June 30, 2016, Delek owned a 59.7% limited partner interest in us, consisting of 14,798,516 common limited partner units and a 95.1% interest in our general partner, which owns the entire 2.0% general partner interest consisting of 495,975 general partner units. Affiliates who are also members of our general partner's management and board of directors own the remaining 4.9% interest in our general partner.

Equity Activity

On February 25, 2016, the requirements under the Partnership Agreement for the conversion of all subordinated units into common units were satisfied and the subordination period ended. As a result, in the first quarter of 2016, each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. The conversion did not impact the amount of the cash distribution paid or the total number of the Partnership's outstanding units representing limited partner interests.

The table below summarizes the changes in the number of units outstanding from December 31, 2015 through June 30, 2016.



	Common - Public	Common - Delek	Subordinated		General Partner	Total
Balance at December 31, 2015	9,478,273	2,799,258	11,999,258		495,445	24,772,234
General partner units issued to maintain 2% interest	—	—	—		530	530
Unit-based compensation awards	25,991	—	—		—	25,991
Subordinated unit conversion	—	11,999,258	(11,999,258	)	—	—
Balance at June 30, 2016	9,504,264	14,798,516	—		495,975	24,798,755

The summarized changes in the carrying amount of our equity from December 31, 2015 through June 30, 2016 are as follows (in thousands):



	Common - Public			Common - Delek			Subordinated - Delek			General Partner			Total
Balance at December 31, 2015	$	198,401		$	(280,828	)	$	78,601		$	(7,192	)	$	(11,018	)
Cash distributions	(11,591		)	(6,255		)	(11,503		)	(4,087		)	(33,436		)
Sponsor contribution of fixed assets	—			597			—			12			609
Net income attributable to partners	11,449			13,906			3,942			5,044			34,341
Unit-based compensation	324			505			—			(596		)	233
Subordinated unit conversion	—			71,040			(71,040		)	—			—
Other	—			—			—			14			14
Balance at June 30, 2016	$	198,583		$	(201,035	)	$	—		$	(6,805	)	$	(9,257	)

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,
	2016			2015			2016			2015
Net income attributable to partners	$	18,893		$	18,311		$	34,341		$	32,951
Less: General partner's IDRs	(2,462		)	(758		)	(4,446		)	(1,364		)
Net income available to partners	$	16,431		$	17,553		$	29,895		$	31,587
General partner's ownership interest	2.0		%	2.0		%	2.0		%	2.0		%
General partner's allocated interest in net income	$	329		$	351		$	598		$	632
General partner's IDRs	2,462			758			4,446			1,364
Total general partner's interest in net income	$	2,791		$	1,109		$	5,044		$	1,996

Incentive Distribution Rights

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and our unitholders in any available cash from operating surplus that we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that (i) our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest, (ii) our general partner has not transferred its IDRs, and (iii) there are no arrearages on common units.



		Target Quarterly Distribution per Unit		Marginal Percentage Interest in Distributions
		Target Amount		Unitholders		General Partner
Minimum Quarterly Distribution		$	0.37500	98.0	%	2.0	%
First Target Distribution	above	$	0.37500	98.0	%	2.0	%
	up to	$	0.43125
Second Target Distribution	above	$	0.43125	85.0	%	15.0	%
	up to	$	0.46875
Third Target Distribution	above	$	0.46875	75.0	%	25.0	%
	up to	$	0.56250
Thereafter	thereafter	$	0.56250	50.0	%	50.0	%

Cash Distributions

Our Partnership Agreement sets forth the calculation to be used to determine the amount and priority of 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 IDRs (in thousands)		Date of Distribution	Unitholders Record Date
June 30, 2015	$	0.550	$	2.20	$	14,368	August 14, 2015	August 6, 2015
September 30, 2015	$	0.570	$	2.28	$	15,136	November 13, 2015	November 6, 2015
December 31, 2015	$	0.590	$	2.36	$	16,124	February 12, 2016	February 5, 2016
March 31, 2016	$	0.610	$	2.44	$	17,095	May 13, 2016	May 5, 2016
June 30, 2016	$	0.630	$	2.52	$	18,085	August 12, 2016⁽¹⁾	August 5, 2016

⁽¹⁾ Expected date of distribution.

The allocation of total quarterly cash distributions expected to be made on August 12, 2016 to general and limited partners for the three and six months ended June 30, 2016 and the allocation of total quarterly cash distributions for the three and six months ended June 30, 2015 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,
	2016		2015		2016		2015
General partner's distributions:
General partner's distributions	$	313	$	272	$	615	$	534
General partner's IDRs	2,462		758		4,446		1,364
Total general partner's distributions	2,775		1,030		5,061		1,898

Limited partners' distributions:
Common	15,310		6,738		25,695		13,213
Subordinated	—		6,600		4,424		12,959
Total limited partners' distributions	15,310		13,338		30,119		26,172
Total cash distributions	$	18,085	$	14,368	$	35,180	$	28,070

Cash distributions per limited partner unit	$	0.630	$	0.550	$	1.240	$	1.080

9. Equity Based Compensation

We incurred approximately $0.1 million and $0.2 million of unit-based compensation expense related to the Partnership during the three and six months ended June 30, 2016, respectively, and $0.1 million and $0.2 million during the three and six months ended June 30, 2015, 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 LTIP is determined based on the closing price of our common limited partner units on the grant date. The estimated fair value of our phantom units is amortized over the vesting period using the straight line method. Awards vest over one to five-year service periods unless such awards are amended in accordance with the LTIP. As of June 30, 2016, there was $1.0 million of total unrecognized compensation cost related to non-vested equity-based compensation arrangements, which is expected to be recognized over a weighted-average period of 1.8 years.

10. Equity Method Investments

In March 2015, the Partnership, through its indirect wholly owned subsidiary DKL Caddo, LLC ("DKL Caddo"), became a member of Caddo Pipeline, LLC ("CP LLC") by entering into an amended and restated limited liability company agreement (the “Caddo LLC Agreement”) with Plains Pipeline, L.P. ("Plains"), an affiliate of Plains All American Pipeline, L.P. CP LLC was formed to plan, develop, construct, own, operate and maintain a pipeline system and certain ancillary assets originating near Longview, Texas and extending to Shreveport, Louisiana (the "Caddo Pipeline System"). Pursuant to the terms of the Caddo LLC Agreement, DKL Caddo and Plains each own a 50% membership interest in CP LLC. Pursuant to separate agreements, Plains will have primary responsibility for the construction of the Caddo Pipeline System, and, upon its completion, Plains will also have primary responsibility for its day-to-day operations.

In March 2015, the Partnership, through its indirect wholly owned subsidiary, DKL RIO, LLC ("DKL RIO"), became a member of Rangeland RIO Pipeline, LLC ("Rangeland RIO") by entering into an amended and restated limited liability company agreement (the "Rangeland LLC Agreement") with Rangeland Energy II, LLC ("Rangeland"). Rangeland RIO was formed to plan, develop, construct, own, operate and maintain a pipeline system and certain ancillary assets extending from Loving County, Texas to Midland, Texas (the "RIO Pipeline"). Pursuant to the terms of the Rangeland LLC Agreement, DKL RIO owns 33% of Rangeland RIO, and Rangeland owns 67%. Rangeland will have primary responsibility for the construction of the RIO Pipeline, and, upon its completion, Rangeland will also have primary responsibility for its day-to-day operations.

The investment in these two entities is expected to be financed through a combination of cash from operations and borrowings under the Second Amended and Restated Credit Agreement. As of June 30, 2016, the investments in these joint ventures totaled $73.4 million and were accounted for using the equity method.

We do not consolidate any part of the assets or liabilities of our equity investees. Our share of net income or loss will increase or decrease, as applicable, the carrying value of our investments in unconsolidated affiliates. With respect to CP LLC and Rangeland RIO, we determined that these entities do not represent variable interest entities and consolidation was not required. We have the ability to exercise influence over each of these joint ventures through our participation in the management committees, which make all significant decisions. However, since all significant decisions require the consent of the other investor(s) without regard to economic interest, we have determined that we have joint control and have applied the equity method of accounting. Our investment in these joint ventures is reflected in our pipelines and transportation segment.

Summarized FInancial Information

Combined summarized financial information for our equity investees is shown below (in thousands):



	June 30, 2016		December 31, 2015
Current assets	$	16,862	$	11,705
Noncurrent assets	$	169,451	$	87,467
Current liabilities	$	5,762	$	4,797
Noncurrent liabilities	$	—	$	—



	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Revenues	$	—		$	—		$	—		$	—
Gross profit	$	—		$	—		$	—		$	—
Net loss	$	(793	)	$	(452	)	$	(1,319	)	$	(452	)

11. Segment Data

We aggregate our operating units 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 sales less cost of sales and operating expenses, excluding depreciation and amortization.

On March 31, 2015, we acquired the Logistics Assets from Delek. Our historical financial statements have been retrospectively adjusted as appropriate to reflect the results of operations attributable to the Logistics Assets as if we owned the assets for all periods presented. The results of the Logistics Assets are included in the pipelines and transportation segment.

The following is a summary of business segment operating performance as measured by contribution margin for the periods indicated (in thousands):



	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016			2015
Pipelines and Transportation
Net Sales:
Affiliate	$	26,136	$	26,093		$	52,442		$	50,078
Third-Party	5,874		7,641			12,351			14,658
Total Pipelines and Transportation	32,010		33,734			64,793			64,736
Operating costs and expenses:
Cost of goods sold	4,814		5,102			9,590			9,915
Operating expenses	6,899		7,745			14,639			14,663
Segment contribution margin	$	20,297	$	20,887		$	40,564		$	40,158
Capital spending (excluding business combinations)	$	718	$	3,057		$	1,424		$	7,610

Wholesale Marketing and Terminalling
Net Sales:
Affiliate	$	10,558	$	13,778		$	23,012		$	22,073
Third-Party	69,285		124,622			128,104			228,837
Total Wholesale Marketing and Terminalling	79,843		138,400			151,116			250,910
Operating costs and expenses:
Cost of goods sold	68,287		127,392			130,264			230,986
Operating expenses	1,831		3,053			4,555			6,912
Segment contribution margin	$	9,725	$	7,955		$	16,297		$	13,012
Capital spending (excluding business combinations)	$	130	$	2,905		$	508		$	5,925

Consolidated
Net Sales:
Affiliate	$	36,694	$	39,871		$	75,454		$	72,151
Third-Party	75,159		132,263			140,455			243,495
Net sales	111,853		172,134			215,909			315,646
Operating costs and expenses:
Cost of goods sold	73,101		132,494			139,854			240,901
Operating expenses	8,730		10,798			19,194			21,575
Contribution margin	30,022		28,842			56,861			53,170
General and administrative expenses	2,698		2,982			5,611			6,391
Depreciation and amortization	4,812		4,744			9,808			9,244
Gain on asset disposals	—		(23		)	(44		)	(18		)
Operating income	$	22,512	$	21,139		$	41,486		$	37,553
Capital spending (excluding business combinations)	$	848	$	5,962		$	1,932		$	13,535

The following table summarizes the total assets for each segment as of June 30, 2016 and December 31, 2015 (in thousands).



	June 30, 2016		December 31, 2015
Pipelines and Transportation	$	309,678	$	283,553
Wholesale Marketing and Terminalling	72,093		91,735
Total Assets	$	381,771	$	375,288

Property, plant and equipment and accumulated depreciation as of June 30, 2016 and depreciation expense by reporting segment for the three and six months ended June 30, 2016 were as follows (in thousands):



	Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
Property, plant and equipment	$	271,899		$	56,312		$	328,211
Less: accumulated depreciation	(58,706		)	(22,367		)	(81,073		)
Property, plant and equipment, net	$	213,193		$	33,945		$	247,138
Depreciation expense for the three months ended June 30, 2016	$	3,920		$	626		$	4,546
Depreciation expense for the six months ended June 30, 2016	$	7,640		$	1,636		$	9,276

In accordance with ASC 360, Property, Plant & Equipment, we evaluate the realizability of property, plant and equipment as events occur that might indicate potential impairment.

12. Fair Value Measurements

The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments.

We apply the provisions of ASC 820, which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to our interest rate and commodity derivatives that are measured at fair value on a recurring basis. The standard also requires that we assess the impact of nonperformance risk on our derivatives. Nonperformance risk is not considered material at this time.

ASC 820 requires disclosures that categorize assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting our assumptions about pricing by market participants.

Over the counter ("OTC") commodity swaps and interest rate swaps and caps are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, spot prices, interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2.

The fair value hierarchy for our financial assets accounted for at fair value on a recurring basis at June 30, 2016 and December 31, 2015 was as follows (in thousands):



	As of June 30, 2016
	Level 1		Level 2			Level 3		Total
Assets
Interest rate derivatives	$	—	$	—		$	—	$	—
OTC commodity swaps	—		50			—		50
Total assets	—		50			—		50
Liabilities
OTC commodity swaps	—		(71		)	—		(71		)
Net liabilities	$	—	$	(21	)	$	—	$	(21	)



	As of December 31, 2015
	Level 1		Level 2			Level 3		Total
Assets
Interest rate derivatives	$	—	$	—		$	—	$	—
OTC commodity swaps	—		171			—		171
Total assets	—		171			—		171
Liabilities
OTC commodity swaps	—		(45		)	—		(45		)
Net assets	$	—	$	126		$	—	$	126

The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. Derivative assets and liabilities with the same counterparty are not netted where the legal right of offset exists. This differs from the presentation in the financial statements which reflects our policy under the guidance of ASC 815-10-45, wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty where the legal right of offset exists.

As of June 30, 2016, $0.1 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2015, $0.8 million of cash collateral was held by counterparty brokerage firms.

13. Derivative Instruments

From time to time, we enter into forward fuel contracts to limit the exposure to price fluctuations for physical purchases of finished products in the normal course of business. We use derivatives to reduce normal operating and market risks with a primary objective in derivative instrument use being the reduction of the impact of market price volatility on our results of operations.

Typically, we enter into forward fuel contracts with major financial institutions in which we fix the purchase price of finished grade fuel for a predetermined number of units with fulfillment terms of less than 90 days.

From time to time, we may also enter into interest rate hedging agreements to limit floating interest rate exposure under the Second Amended and Restated Credit Agreement. Our initial credit facility required us to maintain interest rate hedging arrangements on at least 50% of the amount funded on November 7, 2012 under the credit facility, which was required to be in place for at least a three-year period beginning no later than March 7, 2013. Accordingly, effective February 25, 2013, we entered into interest rate hedges in the form of a LIBOR interest rate cap for a term of three years for a total notional amount of $45.0 million, thereby meeting the requirements in effect at that time. These requirements were eliminated in connection with the Amended and Restated Credit Agreement in July 2013, but the interest rate hedge remained in place in accordance with its terms through its maturity date in February 2016.

The following table presents the fair value of our derivative instruments, as of June 30, 2016 and December 31, 2015. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including any cash collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below may differ from the amounts presented in our consolidated balance sheets. During the three and six months ended June 30, 2016 and June 30, 2015, 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.



(in thousands)		June 30, 2016					December 31, 2015
Derivative Type	Balance Sheet Location	Assets		Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Interest rate derivatives	Other long term assets	$	—	$	—		$	—		$	—
OTC commodity swaps ⁽¹⁾	Other current assets	50		(71		)	171			(45		)
Total gross value of derivatives		50		(71		)	171			(45		)
Less: Counterparty netting and cash collateral ⁽²⁾		13		(71		)	(706		)	(45		)
Total net fair value of derivatives		$	37	$	—		$	877		$	—

⁽¹⁾As of June 30, 2016 and December 31, 2015, we had open derivative contracts representing 123,000 barrels and 171,000 barrels, respectively, of refined petroleum products.

⁽²⁾ As of June 30, 2016, $0.1 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2015, $0.8 million of cash collateral was held by counterparty brokerage firms.

Recognized gains (losses) associated with derivatives not designated as hedging instruments for the three and six months ended June 30, 2016 and 2015 were as follows (in thousands):



		Three Months Ended June 30,						Six Months Ended June 30,
Derivative Type	Income Statement Location	2016			2015			2016			2015
Interest rate derivatives	Interest expense	$	—		$	(4	)	$	—		$	(23	)
Commodity derivatives	Cost of goods sold	(1,282		)	(157		)	(1,459		)	182
	Total	$	(1,282	)	$	(161	)	$	(1,459	)	$	159

14. 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 additional information on a potential enforcement action.

Environmental, Health and Safety

We are subject to extensive and periodically changing federal, state and local laws and regulations relating to the protection of the environment, health and safety. Among other things, these laws and regulations govern the emission or discharge of pollutants into or onto the land, air and water, the handling and disposal of solid and hazardous wastes and the remediation of contamination and the protection of workers and the public. Compliance with existing and anticipated environmental laws and regulations increases our overall cost of business, including our capital costs to develop, maintain, operate and upgrade equipment and facilities. Numerous permits or other authorizations are required under these laws for the operation of our terminals, pipelines, and related operations, and may be subject to revocation, modification and renewal. These laws and permits may become the basis for future claims and lawsuits involving environmental and safety matters, which could include

soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of, or that relate to pre-existing conditions for which we have assumed or are assigned responsibility.

We believe that our current operations are in substantial compliance with existing environmental, health and safety requirements. However, these laws and regulations are subject to changes by regulatory authorities, or to changes in the interpretation of such laws and regulations, by regulatory or judicial authorities. The legislative and regulatory trend has been to place increasingly stringent restrictions and limitations on activities that may affect the environment. Continued and future compliance with such laws and regulations may require us to incur significant expenditures. Violation of environmental laws, regulations and permits can result in the imposition of significant administrative, civil and criminal penalties, monetary fines and penalties, injunctions limiting our operations, investigatory or remedial liabilities or construction bans or delays in the construction of additional facilities or equipment. Additionally, a release of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured or a reimbursable event under the Third Restated 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. These impacts could directly and indirectly affect our business. We cannot currently determine the amounts of such future impacts. There have been and will continue to be ongoing discussions about environmental and safety matters between us and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures.

Crude Oil Releases

We have experienced several crude oil releases involving our assets, including, but not limited to, the following releases:


•	In January 2016, a crude oil release of less than 30 barrels occurred from a gathering line at the Modisette pumping station near El Dorado, Arkansas (the "Modisette Release");


•	In January 2016, a crude oil release of approximately 350 barrels occurred from the Paline Pipeline near Woodville, Texas (the "Paline Release");


•	In April 2015, a crude oil release of an estimated 130 barrels of crude oil was discovered from a gathering line near Fouke, Arkansas (the "Fouke Release"); and


•	In March 2013, a release of approximately 5,900 barrels of crude oil, the majority of which was contained on-site, occurred from a pumping facility at our Magnolia Station located west of the El Dorado Refinery (the "Magnolia Release").

Cleanup operations and site maintenance and remediation efforts on these and other releases have been substantially completed with the exception of the Paline Release, for which remediation is expected to continue through the third quarter of 2016. We may incur additional expenses as a result of further scrutiny by regulatory authorities and continued compliance with laws and regulations to which our assets are subject. As of June 30, 2016, we have accrued $0.2 million for the Paline Release. Expenses incurred for the remediation of crude oil releases are included in operating expenses in our consolidated statements of income and comprehensive income and are subsequently reimbursed by Delek pursuant to the terms of the Third Restated 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 partial 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.

In June 2015, the United States Department of Justice notified the Partnership that it was evaluating an enforcement action on behalf of the Environmental Protection Agency (the "EPA") with regard to potential Clean Water Act violations arising from the Magnolia Release. We are currently attempting to negotiate a resolution to this matter with the EPA and the state of Arkansas, which may include monetary penalties and/or other relief. As of June 30, 2016 we have accrued $1.0 million for the Magnolia Release in connection with these proceedings.

Contracts and Agreements

The majority of the petroleum products we sell in west Texas are purchased from Noble Petro, Inc. ("Noble Petro"). Under the terms of a supply contract (the "Abilene Contract") with Noble Petro, we have the right to purchase up to 20,350 bpd of petroleum products at the Abilene, Texas terminal, which we own, for sales and exchange with third parties at the Abilene and San Angelo terminals. We lease the Abilene and San Angelo, Texas terminals to Noble Petro, under a separate Terminal and Pipeline Lease and Operating Agreement, with a term that runs concurrent with that of the Abilene Contract. The Abilene Contract expires on December 31, 2017 and does not include any options for renewal. We also purchase spot barrels from various third parties and from Delek for sale to wholesale customers in west Texas.

Letters of Credit

As of June 30, 2016, we had in place letters of credit totaling $7.5 million under the Second Amended and Restated Credit Agreement, primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn under these letters of credit at June 30, 2016.

Operating Leases

We lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term to renew the leases. None of these lease arrangements include fixed rental rate increases. Lease expense for all operating leases totaled $0.2 million and $0.5 million for the three and six months ended June 30, 2016, respectively, and $0.4 million and $0.6 million for the three and six months ended June 30, 2015, respectively.

15. Subsequent Events

Distribution Declaration

On July 25, 2016, our general partner's board of directors declared a quarterly cash distribution of $0.630 per limited partner unit, payable on August 12, 2016, to unitholders of record on August 5, 2016.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Unless the context otherwise requires, references in this report to "Delek Logistics Partners, LP," the "Partnership," "we," "us," "our," or like terms, may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. References in this report to "Delek" refer collectively to Delek US Holdings, Inc. and any of its subsidiaries, other than Delek Logistics Partners, LP and its subsidiaries and its general partner. Those statements in this section that are not historical in nature should be deemed forward-looking statements that are inherently uncertain. See "Forward-Looking Statements" below for a discussion of the factors that could cause actual results to differ materially from those projected in these statements.

On March 31, 2015, the Partnership, through its wholly owned subsidiary Delek Logistics Operating, LLC, acquired from Delek two crude oil rail offloading racks, which racks are designed to receive up to 25,000 barrels per day ("bpd") of light crude oil or 12,000 bpd of heavy crude oil, or some combination of the two, delivered by rail to Delek's El Dorado, Arkansas refinery (the "El Dorado Refinery"), and related ancillary assets (the "El Dorado Assets") (such transaction, the "El Dorado Rail Offloading Racks Acquisition").

The El Dorado Rail Offloading Racks Acquisition and the Tyler Crude Tank Acquisition are hereinafter referred to as the "Acquisitions from Delek." The Acquisitions from Delek were accounted for as transfers between entities under common control. As an entity under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of the Partnership have been retrospectively adjusted to include the historical results of the Logistics Assets, as owned and operated by Delek through March 31, 2015 (the "Logistics Assets Predecessor").

You should read the following discussion of our financial condition and results of operations in conjunction with our historical condensed consolidated financial statements and notes thereto.

Forward-Looking Statements

This Quarterly Report on Form 10-Q contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). These forward-looking statements reflect our current estimates, expectations and projections about our future results, performance, prospects and opportunities. Forward-looking statements include, among other things, the information concerning our possible future results of operations, business and growth strategies, financing plans, expectations that regulatory developments or other matters will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, and the benefits and synergies to be obtained from our completed and any future acquisitions, and statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as “may,” “will,” “should,” “could,” “would,” “predicts,” “potential,” “continue,” “expects,” “anticipates,” “future,” “intends,” “plans,” “believes,” “estimates,” “appears,” “projects” and similar expressions, as well as statements in future tense, identify forward-looking statements.

Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to:


•	our substantial dependence on Delek or its assignees and their respective ability to pay us under our commercial agreements;


•	the age and condition of our assets and operating hazards and other risks incidental to transporting, storing and gathering crude oil, intermediate and refined products, including, but not limited to, costs, penalties, regulatory or legal actions and other effects related to spills, releases and tank failures;


•	changes in insurance markets impacting costs and the level and types of coverage available;


•	the timing and extent of changes in commodity prices and demand for refined products;


•	the wholesale marketing margins we are able to obtain and the number of barrels of product we are able to sell in our west Texas wholesale business;


•	the suspension, reduction or termination of Delek's or its assignees' or any third party's obligations under our commercial agreements;


•	the ability to secure commercial agreements from Delek or third parties upon expiration of existing agreements;


•	disruptions due to acts of God, equipment interruption or failure at our facilities, Delek’s facilities or third-party facilities on which our business is dependent;


•	the results of our investments in joint ventures;


•	changes in the availability and cost of capital of debt and equity financing;


•	our reliance on information technology systems in our day-to-day operations;


•	changes in general economic conditions;


•	the effects of existing and future laws and governmental regulations, including, but not limited to, the rules and regulations promulgated by the Federal Energy Regulatory Commission and those relating to environmental protection, pipeline integrity and safety;


•	competitive conditions in our industry;


•	actions taken by our customers and competitors;


•	the demand for crude oil, refined products and transportation and storage services;


•	our ability to successfully implement our business plan;


•	an inability to have growth projects completed on time and on budget;


•	Delek's inability to grow as expected;


•	our ability to successfully integrate acquired businesses;


•	natural disasters, weather-related delays, casualty losses and other matters beyond our control;


•	changes or volatility in interest and inflation rates;


•	labor relations;


•	large customer defaults;


•	changes in tax status;


•	the effects of future litigation; and


•	other factors discussed elsewhere in this Quarterly Report on Form 10-Q and in our Annual Report on Form 10-K for the year ended December 31, 2015.

In light of these risks, uncertainties and assumptions, our actual results of operations and execution of our business strategy could differ materially from those expressed in, or implied by, the forward-looking statements, and you should not place undue reliance upon them. In addition, past financial and/or operating performance is not necessarily a reliable indicator of future performance and you should not use our historical performance to anticipate results or future period trends. We can give no assurances that any of the events anticipated by the forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations and financial condition.

Forward-looking statements speak only as of the date the statements are made. We assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking information except to the extent required by applicable securities laws. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect thereto or with respect to other forward-looking statements.

Business Overview

The Partnership primarily owns and operates crude oil, intermediate and refined products logistics and marketing assets. We gather, transport, offload and store crude oil and intermediate products and market, distribute, transport and store refined products primarily in select regions of the southeastern United States and Texas for Delek and third parties. A substantial majority of our existing assets are both integral to and dependent upon the success of Delek’s refining operations, as many of our assets are contracted exclusively to Delek in support of its Tyler and El Dorado Refineries.

The Partnership is not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of these income taxes, each partner of the Partnership is required to take into account its share of items of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to the partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and the fair market value of our assets and financial reporting bases of assets and liabilities, the acquisition price of their units and the taxable income allocation requirements under the Partnership Agreement.

Our Reporting Segments and Assets

Our business consists of two reportable segments: (i) our pipelines and transportation segment and (ii) our wholesale marketing and terminalling segment.

The assets and investments in our pipelines and transportation segment consist of and have been made in pipelines, tanks, offloading facilities, trucks and ancillary assets, which provide crude oil gathering and crude oil, intermediate and refined products transportation and storage services primarily in support of Delek's refining operations in Tyler, Texas and El Dorado, Arkansas. Additionally, the assets in this segment provide crude oil transportation services to certain third parties. In providing these services, we do not take ownership of the products or crude oil that we transport or store; and, therefore, we are not directly exposed to changes in commodity prices with respect to this operating segment.

The assets in our wholesale marketing and terminalling segment consist of refined products terminals and pipelines in Texas, Tennessee and Arkansas. We generate revenue in our wholesale marketing and terminalling segment by providing marketing services for the refined products output of the Tyler Refinery, engaging in wholesale activity at our terminals in west Texas and at terminals owned by third parties, whereby we purchase light products for sale and exchange to third parties, and by providing terminalling services at our refined products terminals to independent third parties and Delek.

Recent Developments

Inflation Adjustments. On July 1, 2016, the tariffs on our Federal Energy Regulatory Commission ("FERC") regulated pipelines and the throughput fees and storage fees under certain of our agreements with Delek and third parties that are subject to adjustment using FERC indexing decreased by approximately 2.0%, the amount of the change in the FERC oil pipeline index. Under certain of our other agreements with Delek and third parties, the fees increased or decreased based on the consumer price index or the producer price index, which increased approximately 0.7% and decreased approximately 2.6%, respectively. Any applicable decreases to such fees will not result in a reduction to an amount below the fee initially set forth in such agreements.

RIO Pipeline. In March 2015, we entered into a joint venture with an unrelated third party to construct a pipeline system and certain ancillary assets extending from Loving County, Texas to Midland, Texas ("the RIO Pipeline"). The joint venture that will own the RIO Pipeline was formed pursuant to an agreement between our subsidiary DKL RIO, LLC ("DKL RIO") and Rangeland Energy II, LLC ("Rangeland") under which DKL RIO and Rangeland own 33% and 67% membership interests, respectively. Construction on the pipeline was substantially completed in July 2016 and is expected to begin operations in August 2016.

How We Generate Revenue

The Partnership generates revenue by charging fees to Delek and third parties for gathering, transporting, offloading and storing crude oil and for marketing, distributing, transporting, throughputting and storing intermediate and refined products. We also wholesale market refined products in the west Texas market. A substantial majority of our contribution margin, which we define as net sales less cost of goods sold and operating expenses, is derived from commercial agreements with Delek with initial terms ranging from five to ten years, which gives us a contractual revenue base that we believe enhances the stability of our cash flows. As more fully described below, our commercial agreements with Delek typically include minimum volume or throughput commitments by Delek, which we believe will provide a stable revenue stream in the future. The fees charged under our agreements with Delek and third parties are indexed to inflation-based indices. In addition, the rates charged with respect to our assets that are subject to inflation indexing may increase or decrease, typically, on July 1 of each year, by the amount

of any change in various inflation-based indices, provided that in no event will the fees be adjusted below the amount initially set forth in the applicable agreement.

Commercial Agreements

The Partnership has various long-term, fee-based commercial agreements with Delek under which we provide crude oil gathering, crude oil, intermediate and refined products transportation and storage services, and marketing, terminalling and offloading services to Delek, and Delek commits to provide us with minimum monthly throughput volumes of crude oil, intermediate and refined products. Generally, these agreements include minimum quarterly volume, revenue or throughput commitments and have tariffs or fees indexed to inflation-based indices, provided that the tariffs or fees will not be decreased below the initial amount. See our Annual Report on Form 10-K for the year ended December 31, 2015 (our "Annual Report on Form 10-K"), filed with the Securities and Exchange Commission (the "SEC") on February 29, 2016 for a description of certain of our commercial and other agreements with Delek.

How We Evaluate Our Operations

We use a variety of financial and operating metrics to analyze our segment performance. These metrics are significant factors in assessing our operating results and profitability and include: (i) volumes (including pipeline throughput and terminal volumes); (ii) contribution margin and gross margin per barrel; (iii) operating and maintenance expenses; and (iv) EBITDA and distributable cash flow (as such terms are defined below).

Volumes. The amount of revenue we generate primarily depends on the volumes of crude oil, intermediate and refined products that we handle in our pipeline, transportation, terminalling, storage and marketing operations. These volumes are primarily affected by the supply of and demand for crude oil, intermediate and refined products in the markets served directly or indirectly by our assets. Although Delek has committed to minimum volumes under certain of the commercial agreements as described above, our results of operations will be impacted by:


•	Delek’s utilization of our assets in excess of its minimum volume commitments;


•	our ability to identify and execute acquisitions and organic expansion projects, and capture incremental volume increases from Delek or third parties;


•	our ability to increase throughput volumes at our refined products terminals and provide additional ancillary services at those terminals;


•	our ability to identify and serve new customers in our marketing and trucking operations; and


•	our ability to make connections to third-party facilities and pipelines.

Contribution Margin and Gross Margin per Barrel. Because we do not allocate general and administrative expenses by segment, we measure the performance of our segments by the amount of contribution margin generated in operations. Contribution margin is calculated as net sales less cost of sales and operating expenses.

For our wholesale marketing and terminalling segment, we also measure gross margin per barrel. The gross margin per barrel reflects the gross margin (net sales less cost of sales) of the wholesale marketing operations divided by the number of barrels of refined products sold during the measurement period. Both contribution margin and gross margin per barrel can be affected by fluctuations in the prices and cost of gasoline, distillate fuel, ethanol and Renewable Identification Numbers ("RINs"). Historically, the profitability of our wholesale marketing operations has been affected by commodity price volatility, specifically as it relates to changes in the price of refined products between the time we purchase such products from our suppliers and the time we sell the products to our wholesale customers, and the fluctuation in the value of RINs. Commodity price volatility may also impact our wholesale marketing operations when the selling price of finished products does not adjust as quickly as the purchase price. Our wholesale marketing gross margin can also be impacted by fixed price ethanol agreements that we enter into to fix the price we pay for ethanol.

Operating and Maintenance Expenses. We seek to maximize the profitability of our operations by effectively managing operating and maintenance expenses. These expenses are comprised primarily of labor expenses, lease costs, utility costs, insurance premiums, repairs and maintenance expenses and property taxes. These expenses generally remain relatively stable across broad ranges of throughput volumes but can fluctuate from period to period depending on the mix of activities performed during that period and the timing of these expenses. Additionally, compliance with federal, state and local laws and regulations relating to the protection of the environment, health and safety may require us to incur additional expenditures. We will seek to manage our maintenance expenditures on our pipelines and terminals by scheduling maintenance over time to avoid significant variability in our maintenance expenditures and minimize their impact on our cash flow.

EBITDA and Distributable Cash Flow. We define EBITDA as net income (loss) before net interest expense, income tax expense, depreciation and amortization expense. We define distributable cash flow as EBITDA less net cash paid for interest, maintenance capital

expenditures and income taxes. Distributable cash flow will not reflect changes in working capital balances. Distributable cash flow and EBITDA are not presentations made in accordance with accounting principles generally accepted in the United States ("U.S. GAAP").

EBITDA and distributable cash flow are non-U.S. GAAP supplemental financial measures that management and external users of our condensed consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, may use to assess:


•	our operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard to historical cost basis or, in the case of EBITDA, financing methods;


•	the ability of our assets to generate sufficient cash flow to make distributions to our unitholders;


•	our ability to incur and service debt and fund capital expenditures; and


•	the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.

We believe that the presentation of EBITDA and distributable cash flow provides useful information to investors in assessing our financial condition and results of operations. EBITDA and distributable cash flow should not be considered alternatives to net income, operating income, cash from operations or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP. EBITDA and distributable cash flow have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities. Additionally, because EBITDA and distributable cash flow may be defined differently by other companies in our industry, our definition of EBITDA may not be comparable to similarly titled measures of other companies, thereby diminishing its utility. For a reconciliation of EBITDA to its most directly comparable financial measures calculated and presented in accordance with U.S. GAAP, please refer to "Results of Operations—Statement of Operations Data" below.

Factors Affecting the Comparability of Our Financial Results

Our future results of operations may not be comparable to our historical results of operations for the reasons described below:

Revenues. There are differences between the way the Logistics Assets Predecessor recorded revenues and the way the Partnership records revenues after the Acquisitions from Delek. Because our assets, including the Logistics Assets, were historically a part of the integrated operations of Delek, the Logistics Assets Predecessor generally recognized the costs and most revenue associated with the terminalling and storage services provided to Delek on an intercompany basis. Accordingly, the revenues in the Logistics Assets Predecessor's condensed consolidated financial statements are different than those reflected in the Partnership's condensed consolidated financial statements as the Logistics Assets Predecessor's amounts relate primarily to amounts received from third parties while the Partnership's revenues will also reflect amounts associated with our commercial agreements with Delek in addition to amounts received from third parties.

General and Administrative Expenses. The Logistics Assets Predecessor's general and administrative expenses included direct monthly charges for the management and operation of our logistics assets and certain expenses allocated by Delek for general corporate services, such as treasury, accounting and legal services. These expenses were charged or allocated to the Logistics Assets Predecessor based on the nature of the expenses and our proportionate share of employee time and headcount.

Delek continues to charge the Partnership for the management and operation of our logistics assets, including an annual fee under our Omnibus Agreement (as defined in Note 3 to our condensed consolidated financial statements) with Delek, for the provision of various centralized corporate services. Additionally, the Partnership is required to reimburse Delek for direct or allocated costs and expenses incurred by Delek on behalf of the Partnership. The Partnership also incurs additional incremental annual general and administrative expenses as a result of being a publicly traded partnership.

Financing. The Partnership has declared its intent to make a cash distribution to its unitholders at a distribution rate of $0.63 per unit for the quarter ended June 30, 2016 ($2.52 per unit on an annualized basis). Our First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement") requires that the Partnership distribute to its unitholders quarterly all of its available cash as defined in the Partnership Agreement. As a result, the Partnership expects to fund future capital expenditures primarily from operating cash flows, borrowings under our senior secured revolving credit agreement, and any potential future issuances of equity and debt securities.

Market Trends

Master Limited Partnerships

During the year ended December 31, 2015 and continuing through the three and six months ended June 30, 2016, the fluctuation in crude oil prices and the prices of related refined products have impacted our operations and the operations of other master limited partnerships in the midstream energy sector in several ways. First, declines in prices occurring throughout the majority of 2015 and 2016 have resulted in crude oil exploration companies and smaller producers reducing capital expenditures to support future growth, as well as current drilling activity in

many basins. The reduction in drilling activity has created excess capacity and reduced throughput on some crude oil pipelines in the United States and limited the need for new infrastructure projects as crude oil production in the United States began to decline in the second half of 2015. Second, the credit markets have become less liquid in the energy sector during a period of declining prices, which has reduced the availability of credit and increased the cost of debt. Third, due to a challenging market environment and fluctuation in the price per unit for many midstream companies, the yields for master limited partnerships have increased, resulting in a higher cost of capital. The combination of less liquid credit markets, increasing cost of capital and a challenging industry environment affects the ability to develop profitable growth projects that are needed to support future distribution growth in the midstream energy sector.

Overall demand for gathering and terminalling services in a particular area is generally driven by crude oil production in the area, which can be impacted by crude oil prices, refining economics and access to alternate delivery and transportation infrastructure. Additionally, volatility in crude oil, intermediate and refined products prices in the west Texas area and the value attributable to RINs can affect the results of our west Texas operations. For example, declines in the price of crude oil have lowered crude oil production levels in the west Texas area, resulting in lower demand for finished products from our west Texas operations to industries that support crude oil exploration and production. See below for the high, low and average price per barrel of WTI crude oil for each of the quarterly periods in 2015 and the quarterly periods for the six months ended June 30, 2016.

Also, the volatility of finished products prices may reduce our margin in the west Texas operations when the selling price of finished products does not adjust as quickly as the purchase price. See below for the range of prices per gallon of gasoline and diesel for each of the quarterly periods in 2015 and the quarterly periods for the six months ended June 30, 2016.

Our west Texas operations can also benefit from RINs that are generated by ethanol blending activities. As a result, changes in the price of RINs can affect our results of operations. The RINs we generate are sold primarily to Delek at market prices. We sold approximately $1.3 million and $2.9 million of RINs to Delek during the three and six months ended June 30, 2016, respectively, and $2.3 million and $3.9 million during the three and six months ended June 30, 2015, respectively. See below for the high, low and average prices of RINs for each of the quarterly periods in 2015 and the quarterly periods for the six months ended June 30, 2016.

All of these factors are subject to change over time. As part of our overall business strategy, management considers aspects such as location, acquisition and expansion opportunities and factors impacting the utilization of the refineries (and therefore throughput volumes), which may impact our performance in the market.

Seasonality and Customer Maintenance Programs

The volume and throughput of crude oil, intermediate and refined products transported through our pipelines and sold through our terminals and to third parties is directly affected by the level of supply and demand for all such products in the markets served directly or indirectly by our assets or our customers. Supply and demand for such products fluctuates during the calendar year. Demand for gasoline, for example, is generally higher during the summer months than during the winter months due to seasonal increases in motor vehicle traffic. Demand for asphalt products is also lower in the winter months. In addition, our refining customers, such as Delek, occasionally reduce or suspend operations to perform planned maintenance during the winter, when demand for their products is lower. Accordingly, these factors affect the need for crude oil or finished products by our customers and therefore limit our volumes or throughput during these periods, and our operating results will generally be lower during the first and fourth quarters of the year. We believe, however, that many of the potential effects of seasonality on our revenues and contribution margin will be substantially mitigated due to our commercial agreements with Delek that include minimum volume and throughput commitments.

Contractual Obligations

There have been no material changes to our contractual obligations and commercial commitments during the six months ended June 30, 2016 from those disclosed in our Annual Report on Form 10-K.

Critical Accounting Policies

The preparation of our condensed consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. The SEC has defined critical accounting policies as those that are both most important to the portrayal of our financial condition and results of operations and require our most difficult, complex or subjective judgments or estimates. Based on this definition and as further described in our Annual Report on Form 10-K, we believe our critical accounting policies include the following: (i) evaluating impairment for property, plant and equipment and definite life intangibles, (ii) valuing goodwill and potential impairment, and (iii) estimating environmental expenditures. For all financial statement periods presented, there have been no material modifications to the application of these critical accounting policies or estimates since our Annual Report on Form 10-K.

Results of Operations

A discussion and analysis of the factors contributing to our results of operations is presented below. The accompanying condensed consolidated financial statements and related notes of the Partnership have been retrospectively adjusted to include the historical results of the Logistics Assets through June 30, 2015. The financial statements, together with the following information, are intended to provide investors with a reasonable basis for assessing our historical operations, but should not serve as the only criteria for predicting our future performance.

The following table and discussion present a summary of our consolidated results of operations for the three and six months ended June 30, 2016 and 2015, including a reconciliation of EBITDA to net income and net cash provided by (used in) operating activities and distributable cash flow to net income (in thousands, except unit and per unit amounts). Our financial results may not be comparable as the Logistics Assets Predecessor recorded revenues, general and administrative expenses and financed operations differently than the Partnership. See "Factors Affecting the Comparability of Our Financial Results" in this Quarterly Report on Form 10-Q for additional information.



	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016			2015
Statement of Operations Data:	(In thousands, except per unit amounts)
Net sales:
Pipelines and transportation	$	32,010	$	33,734		$	64,793		$	64,736
Wholesale marketing and terminalling	79,843		138,400			151,116			250,910
Total	111,853		172,134			215,909			315,646
Operating costs and expenses:
Cost of goods sold	73,101		132,494			139,854			240,901
Operating expenses	8,730		10,798			19,194			21,575
General and administrative expenses	2,698		2,982			5,611			6,391
Depreciation and amortization	4,812		4,744			9,808			9,244
Gain on asset disposals	—		(23		)	(44		)	(18		)
Total operating costs and expenses	89,341		150,995			174,423			278,093
Operating income	22,512		21,139			41,486			37,553
Interest expense, net	3,284		2,616			6,483			4,773
Loss on equity method investments	206		149			435			149
Total non-operating costs and expenses	3,490		2,765			6,918			4,922
Income before income tax expense	19,022		18,374			34,568			32,631
Income tax expense	129		63			227			317
Net income	18,893		18,311			34,341			32,314
Less: Loss attributable to the Logistics Assets Predecessor	—		—			—			(637		)
Net income attributable to partners	$	18,893	$	18,311		$	34,341		$	32,951
Comprehensive income attributable to partners	$	18,893	$	18,311		$	34,341		$	32,951

Less: General partner's interest in net income, including incentive distribution rights	2,791		1,109			5,044			1,996
Limited partners' interest in net income	$	16,102	$	17,202		$	29,297		$	30,955

Net income per limited partner unit ⁽¹⁾:
Common units - (basic)	$	0.66	$	0.71		$	1.23		$	1.28
Common units - (diluted)	$	0.66	$	0.70		$	1.22		$	1.27
Subordinated units - Delek (basic and diluted)	$	—	$	0.71		$	1.09		$	1.28

Weighted average limited partner units outstanding⁽¹⁾:
Common units - (basic)	24,281,930		12,224,007			20,653,210			12,220,248
Common units - (diluted)	24,367,091		12,360,519			20,735,389			12,350,621
Subordinated units - Delek (basic and diluted)	—		11,999,258			3,626,149			11,999,258

Distributable Cash Flow ⁽²⁾	$	23,713	$	20,943		44,136			$	37,620

⁽¹⁾ We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflect the conversion of the subordinated units to common units on February 25, 2016. See Notes 7 and 8 to our accompanying condensed consolidated financial statements for further discussion.

⁽²⁾For a definition of distributable cash flow, please see "How We Evaluate Our Operations—EBITDA and Distributable Cash Flow" above.



	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(In thousands)
Reconciliation of EBITDA to net income:
Net income	$	18,893		$	18,311		$	34,341		$	32,314
Add:
Income tax expense	129			63			227			317
Depreciation and amortization	4,812			4,744			9,808			9,244
Interest expense, net	3,284			2,616			6,483			4,773
EBITDA ⁽¹⁾	$	27,118		$	25,734		$	50,859		$	46,648

Reconciliation of EBITDA to net cash from operating activities:
Net cash provided by operating activities	$	31,215		$	30,791		$	57,589		$	46,560
Amortization of deferred revenue	383			86			579			221
Amortization of deferred financing costs	(365		)	(365		)	(730		)	(730		)
Accretion of asset retirement obligations	(64		)	(62		)	(131		)	(124		)
Deferred income taxes	—			160			—			(66		)
Loss on equity method investments	(206		)	(149		)	(435		)	(149		)
Gain on asset disposals	—			23			44			18
Unit-based compensation expense	(125		)	(120		)	(233		)	(194		)
Changes in assets and liabilities	(7,133		)	(7,309		)	(12,534		)	(3,978		)
Income tax expense	129			63			227			317
Interest expense, net	3,284			2,616			6,483			4,773
EBITDA⁽¹⁾	$	27,118		$	25,734		$	50,859		$	46,648

Reconciliation of distributable cash flow to EBITDA:
EBITDA ⁽¹⁾	$	27,118		$	25,734		$	50,859		$	46,648
Cash interest, net ⁽²⁾	(2,920		)	(2,251		)	(5,754		)	(4,043		)
Maintenance and regulatory capital expenditures ⁽³⁾	(897		)	(3,928		)	(1,633		)	(7,244		)
Reimbursement from Delek for capital expenditures ⁽⁴⁾	593			1,417			802			2,603
Loss on equity method investments	206			—			435			—
Income tax expense	(129		)	(63		)	(227		)	(317		)
Non-cash unit based compensation expense	125			120			233			194
Amortization of deferred revenue	(383		)	(86		)	(579		)	(221		)
Distributable cash flow ⁽²⁾	$	23,713		$	20,943		$	44,136		$	37,620

⁽¹⁾For a definition of EBITDA and distributable cash flow, please see "How We Evaluate Our Operations—EBITDA and Distributable Cash Flow" above. EBITDA and distributable cash flow include net loss of $0.2 million related to the Logistics Assets Predecessor during the six months ended June 30, 2015.

⁽²⁾Cash interest, net excludes the amortization of debt issuance costs.

⁽³⁾Maintenance and regulatory capital expenditures represent cash expenditures (including expenditures for the addition or improvement to, or the replacement of, our capital assets, and for the acquisition of existing, or the construction or development of new, capital assets) made to maintain our long-term operating income or operating capacity. Examples of maintenance and regulatory capital expenditures are expenditures for the repair, refurbishment and replacement of pipelines and terminals, to maintain equipment reliability, integrity and safety and to address environmental laws and regulations.

⁽⁴⁾ For the three and six month periods ended June 30, 2016 and 2015, Delek reimbursed us for certain capital expenditures pursuant to the terms of the Third Restated Omnibus Agreement (as defined in Note 3 to our condensed consolidated financial statements).

Segment Data:

The following is a summary of business segment capital expenditures for the periods indicated (in thousands):



	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
Capital spending (excluding business combinations)
Pipelines and Transportation	$	718	$	3,057	$	1,424	$	7,610
Wholesale Marketing and Terminalling	$	130	$	2,905	$	508	$	5,925

Consolidated Results of Operations — Comparison of the Three Months Ended June 30, 2016 compared to the Three Months Ended June 30, 2015

The table below presents a summary of our consolidated results of operations and our segment operating performance for the three months ended June 30, 2016 and 2015. The discussion immediately following presents the consolidated results of operations.



	Three Months Ended
	June 30,
	2016		2015
Pipelines and Transportation
Net Sales:
Affiliate	$	26,136	$	26,093
Third-Party	5,874		7,641
Total Pipelines and Transportation	32,010		33,734
Operating costs and expenses:
Cost of goods sold	4,814		5,102
Operating expenses	6,899		7,745
Segment contribution margin	$	20,297	$	20,887

Wholesale Marketing and Terminalling
Net Sales:
Affiliate	$	10,558	$	13,778
Third-Party	69,285		124,622
Total Wholesale Marketing and Terminalling	79,843		138,400
Operating costs and expenses:
Cost of goods sold	68,287		127,392
Operating expenses	1,831		3,053
Segment contribution margin	$	9,725	$	7,955

Consolidated
Net Sales:
Affiliate	$	36,694	$	39,871
Third-Party	75,159		132,263
Net sales	111,853		172,134
Operating costs and expenses:
Cost of goods sold	73,101		132,494
Operating expenses	8,730		10,798
Contribution margin	30,022		28,842
General and administrative expenses	2,698		2,982
Depreciation and amortization	4,812		4,744
Gain on asset disposals	—		(23		)
Operating income	$	22,512	$	21,139

Net Sales

We generated net sales of $111.9 million for the second quarter of 2016 compared to $172.1 million for the second quarter of 2015, a decrease of $60.2 million, or 35.0%. The decrease was primarily attributable to decreases in the average sales prices per gallon of gasoline and diesel and in volumes sold in our west Texas marketing operations. The average sales price per gallon of gasoline sold decreased $0.43 per gallon during the second quarter of 2016 compared to the second quarter of 2015. The average sales price per gallon of diesel sold decreased $0.47 per gallon during the second quarter of 2016 compared to the second quarter of 2015. Further contributing to the decrease were declines in fuel surcharge revenues and fees on our Paline Pipeline System. Partially offsetting the decreases were increased throughput at most of our terminals, including our terminals in El Dorado, Arkansas and Tyler, Texas as operations matched commercial demand.

Cost of Goods Sold

Cost of goods sold was $73.1 million for the second quarter of 2016 compared to $132.5 million for the second quarter of 2015, a decrease of $59.4 million, or 44.8%. The decrease in cost of goods sold was primarily attributable to decreases in the average cost per gallon of gasoline and diesel and in volumes purchased in our west Texas marketing operations. The average cost per gallon of gasoline purchased decreased $0.46 per gallon during the second quarter of 2016, compared to the second quarter of 2015. The average cost per gallon of diesel purchased decreased $0.51 per gallon during the second quarter of 2016 compared to the second quarter of 2015.

Operating Expenses

Operating expenses were $8.7 million for the second quarter of 2016 compared to $10.8 million for the second quarter of 2015, a decrease of $2.1 million, or 19.2%. The decrease in operating expenses in the second quarter of 2016 compared to the second quarter of 2015 was primarily due to decreases in maintenance costs as a result of the completion of maintenance projects at our tank farms, the East Texas Crude Logistics System, the SALA Gathering System and two of our terminals in the west Texas area. Further contributing to the decrease were decreases in insurance expense related to our trucking assets and one of our terminals and reduced expenses associated with our El Dorado Assets. Partially offsetting these decreases were increases in costs associated with the operation of our trucking assets.

Contribution Margin

Contribution margin for the second quarter of 2016 was $30.0 million compared to $28.8 million for the second quarter of 2015, an increase of $1.2 million, or 4.1%. The increase in contribution margin was primarily attributable to increased throughput at most of our terminals, including our terminals in El Dorado, Arkansas and Tyler, Texas as operations matched commercial demand, and higher margins in our west Texas operations. These higher margins in our west Texas operations were achieved as a result of a more

favorable supply/demand balance due to a third-party pipeline outage in the region in late May and early June of 2016, which had a positive impact on our margins but continued to reduce volumes in the area. Also contributing to the increase were reduced operating expenses.

The following table presents a summary of the contribution margin related to our assets for the three months ended June 30, 2016 and 2015.



Contribution Margin
	Three Months Ended June 30,
	2016		2015
	(in thousands)
West Texas	$	2,207	$	1,898
Paline Pipeline	3,907		4,391
Logistics Assets	2,151		1,663
Trucking Assets	290		1,005
East Texas Marketing	4,137		3,921
Terminals	3,838		2,727
Other	13,492		13,237
Total	$	30,022	$	28,842

General and Administrative Expenses

General and administrative expenses were $2.7 million for the second quarter of 2016 compared to $3.0 million for the second quarter of 2015, a decrease of $0.3 million, or 9.5%. The decrease in general and administrative expense was primarily due to decreases in professional services fees for the second quarter of 2016 compared to the second quarter of 2015, during which we incurred greater professional service fees in connection with our acquisition activities. Also contributing to the decrease were decreases in certain direct employee costs allocated to us.

Depreciation and Amortization

Depreciation and amortization was $4.8 million for the second quarter of 2016 compared to $4.7 million for the second quarter of 2015, an increase of $0.1 million, or 1.4%. The increase in depreciation and amortization was primarily due to the addition of assets to our asset base as a result of the completion of capital projects that were placed into service during the second quarter of 2016.

Interest Expense

Interest expense was $3.3 million for the second quarter of 2016 compared to $2.6 million for the second quarter of 2015, an increase of $0.7 million, or 25.5%. This increase was primarily attributable to increases in interest costs under our revolving credit facility due to changes in debt utilization and interest rates thereunder and as a result of borrowings incurred in connection with continued contributions made to our joint ventures.

Income Tax Expense

Income tax expense was $0.1 million for each of the second quarters of 2016 and 2015. Our effective tax rate was 0.7% for the second quarter of 2016, compared to 0.3% for the second quarter of 2015. The Partnership is not subject to federal income taxes as a limited partnership. Accordingly, our taxable income or loss is included in the federal and state income tax returns of our partners. Income tax expense represents amounts incurred for state income taxes.

Consolidated Results of Operations — Comparison of the Six Months Ended June 30, 2016 compared to the Six Months Ended June 30, 2015

The table below presents a summary of our consolidated results of operations and our segment operating performance for the six months ended June 30, 2016 and 2015. The discussion immediately following presents the consolidated results of operations.



	Six Months Ended
	June 30,
	2016			2015
Pipelines and Transportation
Net Sales:
Affiliate	$	52,442		$	50,078
Third-Party	12,351			14,658
Total Pipelines and Transportation	64,793			64,736
Operating costs and expenses:
Cost of goods sold	9,590			9,915
Operating expenses	14,639			14,663
Segment contribution margin	$	40,564		$	40,158

Wholesale Marketing and Terminalling
Net Sales:
Affiliate	$	23,012		$	22,073
Third-Party	128,104			228,837
Total Wholesale Marketing and Terminalling	151,116			250,910
Operating costs and expenses:
Cost of goods sold	130,264			230,986
Operating expenses	4,555			6,912
Segment contribution margin	$	16,297		$	13,012

Consolidated
Net Sales:
Affiliate	$	75,454		$	72,151
Third-Party	140,455			243,495
Net sales	215,909			315,646
Operating costs and expenses:
Cost of goods sold	139,854			240,901
Operating expenses	19,194			21,575
Contribution margin	56,861			53,170
General and administrative expenses	5,611			6,391
Depreciation and amortization	9,808			9,244
Gain on asset disposals	(44		)	(18		)
Operating income	$	41,486		$	37,553

Net Sales

We generated net sales of $215.9 million for the six months ended June 30, 2016 compared to $315.6 million for the six months ended June 30, 2015, a decrease of $99.7 million, or 31.6%. The decrease was primarily attributable to decreases in the average sales prices per gallon of gasoline and diesel and in volumes sold in our west Texas marketing operations. The average sales price per gallon of gasoline sold decreased $0.48 per gallon during the six months ended June 30, 2016 compared to the six months ended June 30, 2015. The average sales price per gallon of diesel sold decreased $0.54 per gallon during the six months ended June 30, 2016 compared to the six months ended June 30, 2015. Partially offsetting the decreases were increased throughput at most of our terminals, including our terminals in El Dorado, Arkansas and Tyler, Texas as operations matched commercial demand, increased fees and lower pipeline allowance losses on our Paline Pipeline System, and the effects of the throughput and tankage agreements for the Logistics Assets, pursuant to which we generated revenue on the acquired assets during the six months ended June 30, 2016, with no comparable revenue earned during the six months ended June 30, 2015. Volumes and fees increased primarily as a result of the turnaround that occurred at the Tyler Refinery in the second quarter of 2015, during which the refinery was not fully operational. Offsetting the increases were decreases in fuel surcharge revenues associated with our trucking assets.

Cost of Goods Sold

Cost of goods sold was $139.9 million for the six months ended June 30, 2016 compared to 240.9 million for the six months ended June 30, 2015, a decrease of $101.0 million, or 44.8%. The decrease in cost of goods sold was primarily attributable to decreases in the average cost per gallon of gasoline and diesel and in volumes purchased in our west Texas marketing operations. The average cost per gallon of gasoline purchased decreased $0.47 per gallon during the six months ended June 30, 2016, compared to the six months ended June 30, 2015. The average cost per gallon of diesel purchased decreased $0.57 per gallon during the six months ended June 30, 2016 compared to the six months ended June 30, 2015.

Operating Expenses

Operating expenses were $19.2 million for the six months ended June 30, 2016 compared to $21.6 million for the six months ended June 30, 2015, a decrease of $2.4 million, or 11.0%. The decrease in operating expenses in the six months ended June 30, 2016 compared to the six months ended June 30, 2015 was due to decreases in maintenance costs as a result of the completion of maintenance projects at our tank farms, the East Texas Crude Logistics System, the SALA Gathering System and two of our terminals in the west Texas area. Partially offsetting these decreases were increases in costs associated with the operation and maintenance of our storage tanks at the El Dorado Refinery and an increase in operating expense for one of our terminal locations related to internal tank contamination.

Contribution Margin

Contribution margin for the six months ended June 30, 2016 was $56.9 million compared to $53.2 million for the six months ended June 30, 2015, an increase of $3.7 million, or 6.9%. The increase in contribution margin was primarily attributable to the increases in net sales discussed above and the decreases in cost of sales and operating expenses, also described above. These increases were partially offset by a decline in margins in our west Texas operations.

The following table presents a summary of the contribution margin related to our assets for the six months ended June 30, 2016 and 2015.



Contribution Margin
	Six Months Ended June 30,
	2016		2015
	(in thousands)
West Texas	$	2,462	$	2,415
Paline Pipeline	9,068		8,259
Logistics Assets	4,053		1,496
Trucking Assets	380		2,121
East Texas Marketing	8,077		6,867
Terminals	6,467		4,655
Other	26,354		27,357
Total	$	56,861	$	53,170

General and Administrative Expenses

General and administrative expenses were $5.6 million for the six months ended June 30, 2016 compared to $6.4 million for the six months ended June 30, 2015, a decrease of $0.8 million, or 12.2%. The decrease in general and administrative expenses was primarily due to decreases in professional services fees for the six months ended June 30, 2016 compared to the six months ended June 30, 2015, during which we incurred greater professional services fees in connection with our various acquisition activities and joint venture projects.

Depreciation and Amortization

Depreciation and amortization was $9.8 million for the six months ended June 30, 2016 compared to $9.2 million for the six months ended June 30, 2015, an increase of $0.6 million, or 6.1%. The increase in depreciation and amortization was primarily due to the addition of the Logistics Assets to our asset base and the completion of capital projects, which were placed into service during the six months ended June 30, 2016 compared to the six months ended June 30, 2015.

Interest Expense

Interest expense was $6.5 million for the six months ended June 30, 2016 compared to $4.8 million for the six months ended June 30, 2015, an increase of $1.7 million, or 35.8%. This increase was primarily attributable to increases in interest costs under our revolving credit facility due to changes in debt utilization and interest rates thereunder and as a result of borrowings incurred in connection with the Acquisitions from Delek and continued contributions made to our joint ventures.

Income Tax Expense

Income tax expense was $0.2 million for the six months ended June 30, 2016, compared to $0.3 million for the six months ended June 30, 2015. Our effective tax rate was 0.7% for the six months ended June 30, 2016, compared to 1.0% for the six months ended June 30, 2015. The Partnership is not subject to federal income taxes as a limited partnership. Accordingly, our taxable income or loss is included in the federal and state income tax returns of our partners. Income tax expense represents amounts incurred for state income taxes.

Operating Segments

We review operating results in two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each reportable segment based on the segment contribution margin. Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization. Segment reporting is more fully discussed in Note 11 to our accompanying condensed consolidated financial statements.

Pipelines and Transportation Segment

Our pipelines and transportation segment assets provide crude oil gathering and crude oil, intermediate and refined products transportation and storage services to Delek and third parties. These assets include the Lion Pipeline System, the SALA Gathering System, the Paline Pipeline System, the East Texas Crude Logistics System, the Tyler-Big Sandy Pipeline, the El Dorado Tank Assets, the Tyler Tank Assets, the Greenville-Mount Pleasant Pipeline and Greenville Storage Facility, the El Dorado Rail Offloading Racks, the Tyler Crude Tank and refined product pipeline capacity leased from Enterprise TE Products Pipeline Company LLC that runs from El Dorado, Arkansas to our Memphis terminal. In addition to these operating systems, we own 123 trucks and 205 trailers used to haul primarily crude oil and other products for unrelated and related third parties.

The following table and discussion present the results of operations and certain operating statistics of the pipelines and transportation segment for the three and six months ended June 30, 2016 and 2015:



	Three Months Ended June 30,		Six Months Ended June 30,
	2016	2015	2016	2015 ⁽¹⁾
Throughputs (average bpd)
Lion Pipeline System:
Crude pipelines (non-gathered)	56,302	53,863	56,322	55,267
Refined products pipelines to Enterprise Systems	53,670	58,572	53,725	57,258
SALA Gathering System	18,288	21,305	18,645	21,421
East Texas Crude Logistics System	12,909	28,677	11,127	23,892

Comparison of the Three Months Ended June 30, 2016 compared to the Three Months Ended June 30, 2015

Net Sales

Net sales for the pipelines and transportation segment were $32.0 million for the second quarter of 2016 compared to $33.7 million for the second quarter of 2015, a decrease of $1.7 million, or 5.1%. The decrease was primarily attributable to the operation of our trucking assets as a result of declines in fuel surcharge revenues and decreased fees on our Paline Pipeline System.

Cost of Goods Sold

Cost of goods sold was $4.8 million for the second quarter of 2016 compared to $5.1 million for the second quarter of 2015, a decrease of 0.3 million, or 5.6%. The decrease in cost of goods sold was attributable to decreased cost of sales on our trucking assets and lower pipeline allowance losses.

Operating Expenses

Operating expenses were $6.9 million for the second quarter of 2016 compared to $7.7 million for the second quarter of 2015, a decrease of $0.8 million, or 10.9%. The decrease in operating expenses was primarily due to decreases in maintenance costs as a result of the completion of maintenance projects at our tank farms, the East Texas Crude Logistics System and the SALA Gathering System in the second quarter of 2016 compared to the second quarter of 2015. Also contributing to the decrease were reduced expenses associated with our El Dorado Assets.

Contribution Margin

Contribution margin for the pipelines and transportation segment was $20.3 million, or 67.6% of our consolidated segment contribution margin in the second quarter of 2016, compared to $20.9 million, or 72.4% of our consolidated segment contribution margin, in the second quarter of 2015, a decrease of $0.6 million, or 2.8%. The decrease in the pipelines and transportation segment contribution margin was primarily attributable to decreases in net sales as described above.

Comparison of the Six Months Ended June 30, 2016 compared to the Six Months Ended June 30, 2015

Net Sales

Net sales for the pipelines and transportation segment were $64.8 million for the six months ended June 30, 2016 compared to $64.7 million for the six months ended June 30, 2015, an increase of $0.1 million, or 0.1%. The increase was primarily attributable to the effects of the throughput and tankage agreements for the Logistics Assets, pursuant to which we generated revenue on the acquired assets during the six months ended June 30, 2016, with no comparable revenue earned during the six months ended June 30, 2015. Also contributing to the increase were increased fees and lower pipeline allowance losses on our Paline Pipeline System in the first half of the period. Offsetting these increases were decreases in net sales associated with our trucking assets as a result of decreases in fuel surcharge revenues.

Cost of Goods Sold

Cost of goods sold was $9.6 million for the six months ended June 30, 2016 compared to $9.9 million for the six months ended June 30, 2015, a decrease of $0.3 million, or 3.3%. The decrease in cost of goods sold was attributable to lower pipeline allowance losses and decreased costs of sales on our trucking assets in the second quarter of 2016.

Operating Expenses

Operating expenses were $14.6 million for the six months ended June 30, 2016 compared to $14.7 million for the six months ended June 30, 2015, a decrease of $0.1 million, or 0.2%. The decrease in operating expenses was primarily due to decreases in maintenance costs as a result of the completion of maintenance projects at our tank farms, the East Texas Crude Logistics System and the SALA Gathering System during the six months ended June 30, 2016 compared to the six months ended June 30, 2015.

Contribution Margin

Contribution margin for the pipelines and transportation segment was $40.6 million, or 71.3% of our consolidated segment contribution margin, in the six months ended June 30, 2016, compared to $40.2 million, or 75.5% of our consolidated segment contribution margin, in the six months ended June 30, 2015, an increase of $0.4 million, or 1.0%. The increase in the pipelines and transportation segment contribution margin was primarily attributable to increases in net sales as described above.

Wholesale Marketing and Terminalling Segment

We use our wholesale marketing and terminalling assets to generate revenue by providing wholesale marketing and terminalling services to Delek’s refining operations and to independent third parties.

The table and discussion below present the results of operations and certain operating statistics of the wholesale marketing and terminalling segment for the three and six months ended June 30, 2016 and 2015:



	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Operating Information:
East Texas - Tyler Refinery sales volumes (average bpd)	70,188		66,860		68,301		47,018
West Texas marketing throughputs (average bpd)	12,594		17,490		13,482		17,070
West Texas marketing margin per barrel	$	2.13	$	1.31	$	1.00	$	1.35
Terminalling throughputs (average bpd)	126,476		113,578		122,645		90,581

Comparison of the Three Months Ended June 30, 2016 compared to the Three Months Ended June 30, 2015

Net Sales

Net sales for the wholesale marketing and terminalling segment were $79.8 million for the second quarter of 2016 compared to $138.4 million for the second quarter of 2015, a decrease of $58.6 million, or 42.3%. The decrease was primarily attributable to decreases in the average sales prices per gallon of gasoline and diesel and in volumes sold in our west Texas marketing operations. The following charts show summaries of the average sales prices per gallon of gasoline and diesel and finished products volume impacting our west Texas operations during the second quarter of 2016 compared to the second quarter of 2015.

Cost of Goods Sold

Cost of goods sold for our wholesale marketing and terminalling segment was $68.3 million in the second quarter of 2016, compared to $127.4 million in the second quarter of 2015, a decrease of $59.1 million, or 46.4%. The decrease in cost of goods sold was attributable to decreases in the average cost per gallon of gasoline and diesel and in volumes purchased in our west Texas marketing operations. See the chart below for a summary of the average purchase prices per gallon of gasoline and diesel impacting our west Texas operations during the second quarter of 2016 compared to the second quarter of 2015.

Operating Expenses

Operating expenses were $1.8 million in the second quarter of 2016, compared to $3.1 million in the second quarter of 2015, a decrease of $1.3 million, or 40.0%. The decrease in operating expenses in the second quarter of 2016 compared to the second quarter of 2015 was primarily due to decreases in costs associated with our assets in our west Texas operations as a result of the completion of maintenance projects at two of our terminals in the area.

Contribution Margin

Contribution margin for the wholesale marketing and terminalling segment was $9.7 million, or 32.4% of our consolidated contribution margin, in the second quarter of 2016, compared to $8.0 million, or 27.6% of our consolidated contribution margin, in the second quarter of 2015, an increase of $1.7 million, or 22.3%. The increase in contribution margin was attributable to increased throughput at most of our terminals, including our terminals in El Dorado, Arkansas and Tyler, Texas as operations matched commercial demand, and higher margins in our west Texas operations. Higher margins in our west Texas operations were achieved as a result of favorable supply/demand balance due to a third-party pipeline outage in the region in late May and early June of 2016, which had a positive impact on our margins but continued to reduce volumes in the area.

Comparison of the Six Months Ended June 30, 2016 compared to the Six Months Ended June 30, 2015

Net Sales

Net sales for the wholesale marketing and terminalling segment were $151.1 million for the six months ended June 30, 2016 compared to $250.9 million for the six months ended June 30, 2015, a decrease of $99.8 million, or 39.8%. The decrease was primarily attributable to decreases in the average sales prices per gallon of gasoline and diesel and in volumes sold in our west Texas marketing operations. The following charts show summaries of the average sales prices per gallon of gasoline and diesel and finished products volume impacting our west Texas operations during the six months ended June 30, 2016 compared to the six months ended June 30, 2015.

Cost of Goods Sold

Cost of goods sold for our wholesale marketing and terminalling segment was $130.3 million for the six months ended June 30, 2016, compared to $231.0 million six months ended June 30, 2015, a decrease of $100.7 million million, or 43.6%. The decrease in cost of goods sold was attributable to decreases in the average cost per gallon of gasoline and diesel and in volumes purchased in our west Texas marketing operations. Also contributing to the decrease in cost of goods sold were lower volumes in our west Texas operations. See the chart below for a summary of the average purchase prices per gallon of gasoline and diesel impacting our west Texas operations during the six months ended June 30, 2016 compared to the six months ended June 30, 2015.

Operating Expenses

Operating expenses were $4.6 million in the six months ended June 30, 2016, compared to $6.9 million in the six months ended June 30, 2015, a decrease of $2.3 million or 34.1%. The decrease in operating expenses in the six months ended June 30, 2016 compared to the six months ended June 30, 2015 was primarily due to decreases in costs associated with our assets in our west Texas operations as a result of the completion of maintenance projects at two of our terminals in the area. Partially offsetting these decreases was an increase in operating expense for one of our terminal locations related to internal tank contamination.

Contribution Margin

Contribution margin for the wholesale marketing and terminalling segment was $16.3 million, or 28.7% of our consolidated contribution margin, for the six months ended June 30, 2016, compared to $13.0 million, or 24.5% of our consolidated contribution margin, for the six months ended June 30, 2015, an increase of $3.3 million, or 25.2%. The increase in contribution margin was attributable to increases in terminalling volumes and increased fees under the Marketing Agreement. Terminalling

volumes and our fees under the Marketing Agreement increased primarily as a result of the turnaround that occurred at the Tyler Refinery in the first quarter of 2015, during which the refinery was not fully operational.

Liquidity and Capital Resources

We expect our ongoing sources of liquidity to include cash generated from operations, borrowings under our revolving credit facility and potential issuances of additional equity and debt securities. We believe that cash generated from these sources will be sufficient to satisfy the anticipated cash requirements associated with our existing operations, including minimum quarterly cash distributions, for at least the next 12 months.

The table below summarizes the quarterly distributions related to our quarterly financial results:



Quarter Ended	Total Quarterly Distribution Per Limited Partner Unit		Total Quarterly Distribution Per Limited Partner Unit, Annualized		Total Cash Distribution, including general partner IDRs (in thousands)		Date of Distribution	Unitholders Record Date
June 30, 2015	$	0.550	$	2.20	$	14,368	August 14, 2015	August 6, 2015
September 30, 2015	$	0.570	$	2.28	$	15,136	November 13, 2015	November 6, 2015
December 31, 2015	$	0.590	$	2.36	$	16,124	February 12, 2016	February 5, 2016
March 31, 2016	$	0.610	$	2.44	$	17,095	May 13, 2016	May 5, 2016
June 30, 2016	$	0.630	$	2.52	$	18,085	August 12, 2016 ⁽¹⁾	August 5, 2016

⁽¹⁾ Expected date of distribution.

Expiration of Subordination Period

In the first quarter of 2016, each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and began participating pro rata with the other common units in distributions of available cash. See Notes 7 and 8 to the condensed consolidated financial statements in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q for additional information.

Cash Flows

The following table sets forth a summary of our consolidated cash flows for the six months ended June 30, 2016 and 2015 (in thousands):



	Six Months Ended June 30,
	2016			2015

Cash Flow Data:
Cash flows provided by operating activities	$	57,589		$	46,560
Cash flows used in investing activities	(35,919		)	(27,541		)
Cash flows used in financing activities	(21,670		)	(20,756		)
Net increase (decrease) in cash and cash equivalents	$	—		$	(1,737	)

Cash Flows from Operating Activities

Net cash provided by operating activities was $57.6 million for the six months ended June 30, 2016, compared to cash provided of $46.6 million for the six months ended June 30, 2015. The increase in cash flows provided by operations was due to decreases in accounts receivable and inventories and other current assets. Accounts receivable decreased as a result of the receipt of an excise tax refund related to finished product purchases from the Tyler Refinery. Inventories and other current assets decreased as a result of lower prices in our west Texas operations. Net income for the six months ended June 30, 2016 was $34.3 million, compared to $32.3 million in the same period of 2015.

Cash Flows from Investing Activities

Net cash used in investing activities was $35.9 million for the first six months of 2016, compared to $27.5 million used in the six months ended June 30, 2015. Cash used in investing activities includes the cash portion of our capital expenditures, which was $3.0 million during the six months ended June 30, 2016. Total capital expenditures during the first six months of 2016 were approximately $1.9 million, of which $1.4 million was spent primarily on maintenance projects in the pipelines and transportation segment and $0.5 million was spent in the wholesale marketing and terminalling segment. This compares to capital expenditures made during the six months ended June 30, 2015 of $13.5 million. Capital expenditures made during the six months ended June 30, 2016 related primarily to maintenance projects on certain of our tanks and crude pipelines, discretionary projects on our terminalling assets and maintenance projects on our Lion Pipeline System, which accounted for approximately $1.2 million, $0.5 million and $0.2 million, respectively, of cash used in investing activities during the six months ended June 30, 2016. Capital expenditures made during the six months ended June 30, 2015 related primarily to discretionary projects on our terminalling assets, the purchase of assets from Delek and maintenance projects on our Lion Pipeline System, which accounted for approximately $7.0 million, $3.8 million and $2.5 million, respectively, of cash used in investing activities. We contributed approximately $33.1 million in cash to our joint ventures during the six months ended June 30, 2016, compared to contributions of approximately $14.8 million during the six months ended June 30, 2015. Partially offsetting the cash used in investing activities during the six months ended June 30, 2015 was an asset sale generating proceeds of approximately $1.2 million.

Cash Flows from Financing Activities

Net cash used in financing activities was $21.7 million in the six months ended June 30, 2016, compared to cash used of $20.8 million in the six months ended June 30, 2015. We paid quarterly cash distributions totaling $33.4 million during the six months ended June 30, 2016, compared to quarterly cash distributions totaling $26.8 million paid during the six months ended June 30, 2015. We had no acquisition activity during the six months ended June 30, 2016, compared to cash paid of $61.9 million in exchange for assets included in the El Dorado Rail Offloading Racks Acquisition and the Tyler Crude Tank Acquisition during the six months ended June 30, 2015. Offsetting the cash used in financing activities during the six months ended June 30, 2016 and 2015 were net proceeds of $11.0 million and $65.2 million, respectively, under the Second Amended and Restated Credit Agreement, as defined below.

Cash Position and Indebtedness

As of June 30, 2016, we had a nominal amount of cash and cash equivalents and we had total indebtedness of approximately $362.6 million. Unused credit commitments under the Second Amended and Restated Credit Agreement were approximately $329.9 million and we had letters of credit issued of $7.5 million. We believe we were in compliance with the applicable covenants in the Second Amended and Restated Credit Agreement as of June 30, 2016.

We entered into a senior secured revolving credit agreement on November 7, 2012, with Fifth Third Bank, as administrative agent, and a syndicate of lenders. The agreement was amended and restated on July 9, 2013 and was most recently amended and restated on December 30, 2014 (the "Second Amended and Restated Credit Agreement"). Under the terms of the Second Amended and Restated Credit Agreement, the lender commitments were increased from $400.0 million to $700.0 million. The Second Amended and Restated Credit Agreement also contains an accordion feature whereby the Partnership can increase the size of the credit facility to an aggregate of $800.0 million, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. While the majority of the terms of the Second Amended and Restated Credit Agreement are substantially unchanged from the predecessor facility, among other things, changes were made to certain negative covenants, the financial covenants and the interest rate pricing grid. The Second Amended and Restated Credit Agreement contains an option for Canadian dollar denominated borrowings. The Second Amended and Restated Credit Agreement matures on December 30, 2019.

See Note 5 to the condensed consolidated financial statements in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q for a complete discussion of our third-party indebtedness.

Agreements Governing Certain Indebtedness of Delek

Although we are not contractually bound by and are not liable for Delek’s debt under its credit arrangements, we are indirectly affected by certain prohibitions and limitations contained therein. Specifically, certain of Delek's credit arrangements require that Delek meets certain minimum levels for (i) consolidated shareholders’ equity and (ii) a ratio of consolidated shareholders’ equity to adjusted total assets. We cannot assure you that such covenants will not impact our ability to use the full capacity under our revolving credit facility in the future. Delek, due to its majority ownership and control of our general partner, has the ability to prevent us from taking actions that would cause Delek to violate any covenant in its credit arrangements or otherwise be in default under any of its credit arrangements.

Capital Spending

A key component of our long-term strategy is our capital expenditure program. Our capital expenditures for the six months ended June 30, 2016 were $1.9 million, of which approximately $1.4 million was spent in our pipelines and transportation segment and $0.5 million was spent in our wholesale marketing and terminalling segment. Our capital expenditure budget is approximately $14.3 million for 2016.

The following table summarizes our actual capital expenditures for the six months ended June 30, 2016 and planned capital expenditures for the full year 2016 by operating segment and major category (in thousands):



	Full Year 2016 Forecast		Six Months Ended June 30, 2016
Regulatory	$	1,467	$	115
Maintenance ⁽¹⁾	9,344		1,182
Discretionary projects	3,478		635
Total capital spending	$	14,289	$	1,932

⁽¹⁾

Maintenance capital expenditures represent cash expenditures (including expenditures for the addition or improvement to, or the replacement of, our capital assets, and for the acquisition of existing, or the construction or development of new, capital assets) made to maintain our long-term operating income or operating capacity. Examples of maintenance capital expenditures are expenditures for the repair, refurbishment and replacement of pipelines and terminals, to maintain equipment reliability, integrity and safety and to address environmental laws and regulations. Delek has agreed to reimburse us with respect to certain assets it has transferred to us pursuant to the terms of the Omnibus Agreement (as defined in Note 3 to our condensed consolidated financial statements).

For the full year 2016, we plan to spend approximately $14.3 million, of which $11.4 million is budgeted to the pipelines and transportation segment and $2.9 million to the wholesale marketing and terminalling segment. We plan to spend approximately $3.5 million for discretionary projects in 2016, of which $2.0 million will be spent in the pipelines and transportation segment and $1.5 million in the wholesale marketing and terminalling segment. The majority of the $2.0 million budgeted to discretionary projects in the pipelines and transportation segment relates to maintaining our SALA Gathering System and Lion Pipeline assets. We plan to spend approximately $9.3 million for maintenance projects in 2016, of which $8.1 million will be spent in the pipelines and transportation segment and $1.2 million in the wholesale marketing and terminalling segment. Of the $8.1 million budgeted to the pipelines and transportation segment, $7.5 million relates to the repair and replacement of certain of our tanks.

In addition to the capital spending above, in March 2015, we entered into two joint ventures with unrelated third parties to construct logistics assets. Our total projected investment for the two joint ventures, which is subject to change pending revisions in construction schedules, is approximately $99.0 million. As of June 30, 2016, we have contributed $74.2 million to these joint ventures. Construction on the RIO Pipeline (as defined in Note 10 to our condensed consolidated financial statements) was substantially completed in July 2016 and is expected to begin operations in August 2016. Construction on the Caddo Pipeline (as defined in Note 10 to our condensed consolidated financial statements) is expected to be completed by January 2017. These expenditures are recorded to equity method investments in the accompanying condensed consolidated balance sheet.

Under the Third Restated Omnibus Agreement, Delek reimburses us for (i) certain expenses that we incur for inspections, maintenance, repairs and failures of certain assets we acquired from Delek to cause such assets to comply with applicable regulatory and/or industry standards, (ii) certain expenses that we incur for inspections, maintenance, repairs and failures of most of the storage tanks and pipelines contributed to us by Delek (subject to a deductible of $0.5 million per year for certain assets as specified in the Third Restated Omnibus Agreement) that are necessary to comply with minimum standards under certain United States Department of Transportation pipeline integrity rules and certain American Petroleum Institute storage tank standards for a period of five years from the date of the purchase of the affected assets, and (iii) for certain non-discretionary maintenance capital expenditures with respect to certain of our assets in excess of specified amounts, as disclosed in the full agreement filed as Exhibit 10.3 to our Current Report on Form 8-K, filed with the SEC on April 6, 2015 and in the amendment filed as Exhibit 10.2 to our Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, filed with the SEC on August 5, 2015.

The amount of our capital expenditure budget is subject to change due to unanticipated increases in the cost, scope and completion time for our capital projects. For example, we may experience increases in the cost of and/or timing to obtain necessary equipment required for our continued compliance with government regulations or to complete improvement projects. Additionally, the scope and cost of employee or contractor labor expense related to installation of that equipment could increase from our projections.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements through the date of the filing of this Quarterly Report on Form 10-Q.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk. Market risk is the risk of loss arising from adverse changes in market rates and prices. As we do not take title to any of the crude oil that we handle, and typically we take title to only limited volumes of light products in our marketing business, we have limited direct exposure to risks associated with fluctuating commodity prices. However, from time to time, we enter into Gulf Coast product swap arrangements with respect to the products we purchase to hedge our exposure to fluctuations in commodity prices for the period between our purchase of products and subsequent sales to our customers. At June 30, 2016, we had open derivative contracts representing 123,000 barrels of refined petroleum products. At December 31, 2015, we had open derivative contracts representing 171,000 barrels of refined petroleum products. We recognized (losses) gains associated with derivatives not designated as hedging instruments of $(1.3) million and $(1.5) million for the three and six months ended June 30, 2016, respectively, and $(0.2) million and $0.2 million for the three and six months ended June 30, 2015, respectively. These amounts were recorded to cost of goods sold in the accompanying condensed consolidated statements of income. Please see Note 13 to our accompanying condensed consolidated financial statements for additional detail related to our derivative instruments. In addition, the Partnership's commercial agreements with Delek are indexed to inflation.

Impact of Changing Prices. Our revenues and cash flows, as well as estimates of future cash flows, are sensitive to changes in energy prices. Shifts in the cost of crude oil, the prices of refined products and the cost of ethanol can generate changes in the operating margin in our wholesale marketing and terminalling segment. A hypothetical ten percent adverse change in year-end market prices of the underlying commodities being hedged by derivative contracts would result in a nominal decrease in market value at June 30, 2016. This hypothetical loss was estimated by multiplying the difference between the hypothetical and the actual year-end market prices of the underlying commodities by the contract volume amounts.

Interest Rate Risk. Debt that we incur under our revolving credit facility bears interest at floating rates and will expose us to interest rate risk. The annualized impact of a hypothetical one percent change in interest rates on our floating rate debt outstanding as of June 30, 2016 would be to change interest expense by approximately $3.6 million.

From time to time, we may use certain derivative instruments to hedge our exposure to floating interest rates. Additionally, our prior revolving credit facility required us to maintain interest rate hedging arrangements with respect to at least 50% of the amount funded on November 7, 2012 under the credit facility, which was required to be in place for at least a three-year period beginning no later than March 7, 2013. Accordingly, effective February 25, 2013, we entered into interest rate hedges in the form of a London Interbank Offered Rate interest rate cap for a term of three years for a total notional amount of $45.0 million, thereby meeting the requirements in effect at that time. These requirements were eliminated in connection with the amendment and restatement of our revolving credit facility in July 2013, but the interest rate hedge remained in place in accordance with its terms through its maturity date in February 2016. The estimated fair value of our interest rate derivative asset was zero as of December 31, 2015. In accordance with ASC 815, Derivatives and Hedging, we recorded no non-cash expense representing the change in estimated fair value of the interest rate hedge agreement for each of the three and six months ended June 30, 2016 and a nominal amount for each of the three and six months ended June 30, 2015.

ITEM 4. CONTROLS AND PROCEDURES.

(a) Evaluation of Disclosure Controls and Procedures

Our management has evaluated, with the participation of our principal executive and principal financial officers, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) or Rule 15d-15(e) under the Exchange Act as of the end of the period covered by this report, and has, based on this evaluation, concluded that our disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms including, without limitation, controls and procedures designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers, as appropriate to allow timely decisions regarding required disclosures.

(b) Changes in Internal Control over Financial Reporting

There has been no change in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act that occurred during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II.

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Although we may, from time to time, be involved in litigation and claims, whether regulatory or other, arising out of our operations in the normal course of business, we do not believe that we are a party to any litigation that will have a material adverse impact on our financial condition, results of operations or cash flows. However, in June 2015, the United States Department of Justice notified us that they were evaluating an enforcement action on behalf of the EPA with regard to potential Clean Water Act violations arising from the March 2013 Magnolia Station release. We are currently attempting to negotiate a resolution to this matter with the EPA and the State of Arkansas, which may include monetary penalties and/or other relief.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Unregistered Sales of Equity Securities

Pursuant to the terms of our limited partnership agreement, our general partner has the right to maintain its proportionate 2% general partner interest in the Partnership. The following table provides information regarding the exercise of such right by our general partner. The sale listed below was exempt from registration under Section 4(a)(2) of the Securities Act.

⁽¹⁾ Proceeds are used for general corporate purposes.

ITEM 6. EXHIBITS



Exhibit No.		Description
10.1	§	Amendment to Throughput and Tankage Agreement (El Dorado Terminal and Tankage), dated as of July 22, 2016, but effective as of February 11, 2014, by and between Lion Oil Company and Delek Logistics Operating, LLC
10.2	§ *	General Terms and Conditions for Phantom Unit Awards under the Delek Logistics GP, LLC 2012 Long-Term Incentive Plan
31.1	§	Certification of Delek Logistics GP, LLC's Chief Executive Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
31.2	§	Certification of Delek Logistics GP, LLC's Chief Financial Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
32.1	§	Certification of Delek Logistics GP, LLC's Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	§	Certification of Delek Logistics GP, LLC's Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101		The following materials from Delek Logistics Partners, LP’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2016 formatted in XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015 (Unaudited), (ii) Condensed Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2016 and 2015 (Unaudited), (iii) Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2016 and 2015 (Unaudited), and (iv) Notes to Condensed Consolidated Financial Statements (Unaudited).



§		Filed herewith
*		Management contract or compensatory plan or arrangement

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.



Delek Logistics Partners, LP
By:	Delek Logistics GP, LLC
	Its General Partner

By:	/s/ Ezra Uzi Yemin
	Ezra Uzi Yemin
	Chairman and Chief Executive Officer (Principal Executive Officer)

By:	/s/ Assaf Ginzburg
	Assaf Ginzburg
	Director, Executive Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)

Dated: August 5, 2016

EXHIBIT INDEX



Exhibit No.		Description
10.1	§	Amendment to Throughput and Tankage Agreement (El Dorado Terminal and Tankage), dated as of July 22, 2016, but effective as of February 11, 2014, by and between Lion Oil Company and Delek Logistics Operating, LLC
10.2	§ *	General Terms and Conditions for Phantom Unit Awards under the Delek Logistics GP, LLC 2012 Long-Term Incentive Plan
31.1	§	Certification of Delek Logistics GP, LLC's Chief Executive Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
31.2	§	Certification of Delek Logistics GP, LLC's Chief Financial Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
32.1	§	Certification of Delek Logistics GP, LLC's Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	§	Certification of Delek Logistics GP, LLC's Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101		The following materials from Delek Logistics Partners, LP’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2016 formatted in XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets as of June 30, 2016 and December 31, 2015 (Unaudited), (ii) Condensed Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2016 and 2015 (Unaudited), (iii) Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2016 and 2015 (Unaudited), and (iv) Notes to Condensed Consolidated Financial Statements (Unaudited).



§		Filed herewith
*		Management contract or compensatory plan or arrangement