Attached files

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EX-32.2 - EX32.2-CFO CERTIFICATION - Delek Logistics Partners, LPdkl-ex322xcfocertification.htm
EX-32.1 - EX32.1-CEO CERTIFICATION - Delek Logistics Partners, LPdkl-ex321xceocertification.htm
EX-31.2 - EX31.2-CFO CERTIFICATION - Delek Logistics Partners, LPdkl-ex312xcfocertification.htm
EX-31.1 - EX31.1-CEO CERTIFICATION - Delek Logistics Partners, LPdkl-ex311xceocertification.htm
EX-24.1 - EX24.1-POWER OF ATTORNEY - Delek Logistics Partners, LPdkl-ex241xpoax123116.htm
EX-23.1 - EX23.1-EY CONSENT - Delek Logistics Partners, LPdkl-ex231xeyconsentx123116.htm
EX-21.1 - EX21.1-SUBSIDIARY LISTING - Delek Logistics Partners, LPdkl-ex211xsubsidiarylistin.htm
EX-10.1 - EX10.1-SECOND AMENDMENT TO MARKETING AGREEMENT - Delek Logistics Partners, LPdkl-ex101x10xkxsecondamend.htm


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
(Mark One)
þ
 
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
 
 
 
 
 
For the Fiscal Year Ended December 31, 2016
OR
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)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Name of each exchange on which registered
 
 
Common Units Representing Limited Partner Interests
New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:
None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.  Yes o No þ

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes o No þ

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 (Section 232.405 of this chapter) 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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (section 232.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendments of this Form 10-K.  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. (Check one):

Large accelerated filer     o    Accelerated filer  þ        Non-accelerated filer o    Smaller reporting company o
(Do not check if a smaller reporting company)

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

The aggregate market value of the registrant's common limited partner units held by non-affiliates as of June 30, 2016 was approximately $253,858,891, based upon the closing price of its common units on the New York Stock Exchange on that date.

At February 17, 2017, there were 24,328,607 common limited partner units and 496,502 general partner units outstanding.

Documents incorporated by reference: None




TABLE OF CONTENTS
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

2




Unless otherwise indicated or the context requires otherwise, 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.

Statements in this Annual Report on Form 10-K, other than purely historical information, including statements regarding our plans, strategies, objectives, beliefs, expectations and intentions are forward-looking statements. These forward-looking statements generally are identified by the words “may,” “will,” “should,” “could,” “would,” “predicts,” “intends,” “believes,” “expects,” “plans,” “scheduled,” “goal,” “anticipates,” “estimates” and similar expressions. Forward-looking statements are based on current expectations and assumptions that are subject to risks and uncertainties, including those discussed below and in Item 1A, Risk Factors, which may cause actual results to differ materially from the forward-looking statements. See also “Forward-Looking Statements” included in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations included in Item 1, Business, of this Annual Report on Form 10-K.
    
PART I

ITEM 1.  BUSINESS

General

Delek Logistics Partners, LP is a Delaware limited partnership formed in April 2012 by Delek US Holdings, Inc. ("Delek") and its indirect subsidiary, Delek Logistics GP, LLC, which is our general partner ("GP" or "general partner"). Unless otherwise indicated or the context requires, "Delek" and "Sponsor" refer collectively to Delek and any of its subsidiaries, other than the Partnership, its subsidiaries and its general partner. In November 2012, the Partnership completed its initial public offering (the "Offering").

The Partnership's business primarily consists of certain crude oil, intermediate and refined products pipelines and transportation, storage, wholesale marketing, terminalling and offloading assets which were previously owned, operated or held by Delek and assets acquired from unrelated third parties. Irrespective of the party from whom we acquired our assets, Delek is our primary or sole customer for a substantial majority of our assets and is responsible, directly or indirectly, for the majority of our gross margin (as defined below).

Overview

The Partnership primarily owns and operates logistics and marketing assets for crude oil and intermediate and refined products. We generate revenue and contribution margin, which we define as net sales less cost of goods sold and operating expenses, by charging fees for gathering, transporting, offloading and storing crude oil, for storing intermediate products and feed stocks, and for marketing, wholesale marketing, distributing, transporting and storing refined products. A substantial majority of our existing assets are both integral to and dependent on the success of Delek's refining operations and most of our assets are contracted exclusively to Delek in support of Delek's refineries in Tyler, Texas (the "Tyler Refinery") and El Dorado, Arkansas (the "El Dorado Refinery"). See "—Commercial Agreements—Commercial Agreements with Delek" and Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for a discussion of our material commercial agreements with Delek. In addition to the services we provide to Delek, we also provide, and generate substantial revenue and contribution margin from, crude oil, intermediate and refined products transportation services for, and terminalling and marketing services to, third parties primarily in Texas, Tennessee and Arkansas. Certain of these services are provided pursuant to contractual agreements with such third parties. See "—Commercial Agreements—Other Agreements with Third Parties."

We are not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of such 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 such 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 the partner's units and the taxable income allocation requirements under the Partnership's First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement").

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Recent Developments

Paline Pipeline Hydro Test.  In August 2016, we successfully completed a hydro test on our Paline Pipeline. This test is required to be completed every five years by the Pipeline and Hazardous Materials Safety Administration ("PHMSA"). We spent approximately $1.0 million on the hydro test, of which $0.5 million was included in operating expenses and $0.5 million was included in capital expenditures.

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 our agreements with Delek.

Subordinated Unit Conversion. 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 5 and 12 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for additional information.

Joint Ventures.  During 2016, we substantially completed construction of assets held by two joint ventures with unrelated third parties. These assets include the following:

an 80-mile crude oil pipeline with a capacity of 80,000 barrels per day ("bpd") that originates in Longview, Texas with destinations in the Shreveport, Louisiana area (the "Caddo Pipeline"); and
a 107-mile crude oil pipeline with a capacity of 55,000 bpd, with the capability to expand to 85,000 bpd, that originates in north Loving County, Texas near the Texas-New Mexico border and terminates in Midland, Texas (the "RIO Pipeline").

The joint venture that owns the Caddo Pipeline was formed pursuant to an agreement between our subsidiary DKL Caddo, LLC ("DKL Caddo") and Plains Pipeline, L.P., an affiliate of Plains All American Pipeline, L.P. ("Plains"), under which DKL Caddo and Plains each own a 50% membership interest. Operations on the Caddo Pipeline began in January 2017.

The joint venture that owns 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. Operations on the RIO Pipeline began in September 2016.


4



Assets and Operations

We prepare segment information on the same basis that we review financial information for operational decision-making purposes. Currently, our business consists of two operating segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. Additional segment and financial information is contained in our segment results included in Item 6, Selected Financial Data; Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations; and Note 15, Segment Data, of our consolidated financial statements included in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. Our principal assets, as of December 31, 2016, are described below under the segment that uses such assets.

The following provides an overview of our assets and operations:

dklregionalmap5112015a03.jpg

Pipelines and Transportation Segment

Our pipelines and transportation segment consists of assets, including pipelines and trucks and ancillary assets, that provide crude oil gathering and crude oil, intermediate and finished products transportation and storage services primarily in support of the Tyler and El Dorado Refineries. Additionally, this segment provides crude oil and other products transportation services to certain unrelated third parties. In providing these services, we do not take ownership of the products or crude oil that we transport or store; and, therefore, the results of our pipelines and transportation segment are not directly exposed to changes in commodity prices. Our pipeline assets include approximately 400 miles of operable crude oil transportation pipelines, approximately 366 miles of refined product pipelines and approximately 600 miles of crude oil gathering and trunk lines. Associated with and currently used in connection with the operation of these lines are crude oil, intermediate and refined products storage tanks with an aggregate of approximately 7.3 million barrels of active shell capacity. We also own 123 trucks and 205 trailers used to haul primarily crude oil, finished products and other hydrocarbon products for unrelated and related third parties.
 
The tables below show the operating results for each of our operating systems within this segment for the years ended December 31, 2016, 2015 and 2014.



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Lion Pipeline System. Our Lion Pipeline System is a system of common carrier pipelines that transport crude oil to, and refined products from, Delek's El Dorado Refinery. The Lion Pipeline System consists primarily of:

the Magnolia Pipeline system;
the El Dorado Pipeline system;
multiple short crude oil pipelines located at the El Dorado Refinery and our Sandhill Station;
the Magnolia Station located west of the El Dorado Refinery;
a Refined Products Pipeline system (as defined and described below); and
certain related crude oil pipelines.

The Magnolia Pipeline is an approximately 77-mile crude oil pipeline, with a capacity of approximately 68,500 bpd, that runs from a connection with ExxonMobil’s LOLA System near Shreveport, Louisiana to our Magnolia Station, where the crude oil is then stored and transferred to our El Dorado Pipeline. In addition, third-party pipelines connect the Magnolia Pipeline near Haynesville, Louisiana, which allows for the receipt of crude oil transported from Longview, Texas. The service provided on the Magnolia Pipeline is regulated by the FERC and is subject to FERC tariffs.

The El Dorado Pipeline is a 28-mile, 12-inch crude oil pipeline, with a capacity of approximately 22,000 bpd, that transports crude oil from our Magnolia Station to Delek's Sandhill Station adjacent to the El Dorado Refinery. The service provided on the El Dorado Pipeline is regulated by the FERC and is subject to FERC tariffs. Upon reaching the Sandhill Station, the crude oil from the El Dorado Pipeline is transported, via multiple short crude oil pipelines owned by us, to Tank 192, a 150,000 barrel capacity storage tank located at Delek's Sandhill Station ("Tank 192"). At present, substantially all crude oil that enters the El Dorado Refinery, including the crude oil gathered on the SALA Gathering System, is first routed to Tank 192. Through our SALA subsidiary, we own Tank 192 and lease the underlying ground from Lion Oil under a long-term ground lease.

The Magnolia Station is a location, owned by us, where the Magnolia and Lion Pipelines and SALA Gathering System have origination and destination points, as the case may be. In addition, the Magnolia Station has storage facilities with approximately 220,000 barrels of active shell capacity, which includes the addition of a new 85,000 barrel crude oil storage tank in the fourth quarter of 2016.

We also own two refined product pipelines that transport gasoline and diesel from the El Dorado Refinery to the nearby Enterprise TE Products Pipeline El Dorado Station (the “Refined Products Pipelines”). Pursuant to a capacity lease with Enterprise dated October 24, 2013, we also lease capacity of approximately 11,000 bpd on the Enterprise Products Pipeline from Enterprise's El Dorado Station to our refined products terminal in Memphis, Tennessee. The Refined Products Pipelines along with the leased capacity are collectively referred to as the "Refined Products Pipeline System." The service provided on the Refined Products Pipelines is regulated by the FERC and is subject to a FERC tariff. The diesel line is 12 inches in diameter, while the gasoline line is 10 inches in diameter. These two lines commence at the El Dorado Refinery.

The pipelines in the Lion Pipeline System also have injection points where crude oil gathered from the SALA Gathering System can be injected and then transported to the El Dorado Refinery. Movements from the SALA Gathering System onto the Lion Pipeline System to the El Dorado Refinery are subject to a joint tariff for the transportation of these volumes that is on file with the FERC for both the SALA Gathering System and the El Dorado Pipeline; the joint rate for these movements is equal to the rate that would apply for movements only on the SALA Gathering System to the connection point with the Lion Pipeline System. The Lion Pipeline System has crude oil storage tanks and facilities ancillary to the operation of the pipeline system. The Lion Pipeline System is capable of transporting crude oil offloaded from rail cars at or near the El Dorado Refinery, including at the two crude oil rail offloading racks we acquired in March 2015. See "El Dorado Rail Offloading Racks" below.


6



The following table details certain operating data for our Lion Pipeline System.
 
 
Average Daily Throughput (bpd)
 
 
Year Ended
 
 
December 31,
 
 
2016
 
2015
 
2014
Lion Pipeline System:
 
 
 
 
 
 
Crude Oil Pipelines (Non-gathered) (1)
 
56,555
 
54,960
 
47,906
Refined Products Pipelines to Enterprise System
 
52,071
 
57,366
 
53,461
            

(1) 
Excludes crude oil gathered on our SALA Gathering System and injected into our Lion Pipeline System.

SALA Gathering System. The SALA Gathering System is a system of common carrier pipelines that primarily gathers and transports crude oil and condensate that is purchased from various crude oil producers in Arkansas, Texas and Louisiana by Delek or a third party to whom Delek has assigned certain of its rights. Service on the SALA Gathering System is regulated by the FERC and is subject to tariffs on file with the FERC. The SALA Gathering System includes approximately 600 miles of two- to eight-inch crude oil gathering and transportation lines in southern Arkansas and northern Louisiana, located primarily within a 60-mile radius of the El Dorado Refinery. In addition, the gathering system transports small volumes of crude oil that are received from other sources and condensate that is purchased from a third party in east Texas. All such crude oil and other products are ultimately transported to the El Dorado Refinery for processing. In addition, a pipeline within the SALA Gathering System transports minimal crude oil for third party shippers pursuant to a common carrier tariff.

The SALA Gathering System includes 53 crude oil storage tanks and breakout tanks with a total combined active shell capacity of approximately 0.8 million barrels (including Tank 192 and approximately 42,000 barrels of capacity we lease to an unrelated third party), 14 truck receipt locations, approximately 500 pipeline gathering and receiving stations and 17 relay stations to deliver crude oil to the Magnolia Station, the El Dorado Pipeline System or directly to the El Dorado Refinery. We also have approximately 0.5 million barrels of combined shell capacity that is currently not in service. The table below sets forth historical throughput information for the SALA Gathering System.

 
 
Average Daily Throughput (bpd)
 
 
Year Ended
 
 
December 31,
 
 
2016
 
2015
 
2014
SALA Gathering System:
 
 
 
 
 
 
Throughput (average bpd):
 
17,756
 
20,673
 
22,656

Paline Pipeline System. Our Paline Pipeline System is primarily a 195-mile, 10-inch crude oil pipeline, with a capacity of approximately 36,000 bpd, running from Longview, Texas to the Phillips 66-operated Beaumont terminal in Nederland, Texas. It includes a three-mile section that runs north from Kilgore, Texas. Our Paline Pipeline System is operated as a common carrier pipeline and the service is regulated by the FERC. See Item 1, Business—Commercial Agreements—Other Agreements with Third Parties—Paline Pipeline System Capacity Reservation" for additional information on the use of our Paline Pipeline System.  

East Texas Crude Logistics System. Our East Texas Crude Logistics System includes two owned and operated crude oil pipeline systems and their related tank farms, which serve the Tyler Refinery: (i) the Nettleton pipeline, a bi-directional 36-mile pipeline, with a capacity of approximately 38,000 bpd, that is capable of transporting crude oil from our tank farms in and around Longview, Texas to (a) the Bullard Junction at the Tyler Refinery and (b) to other of our tank farms in and around Longview, Texas, and (ii) the McMurrey Pipeline System, a 65-mile pipeline system, with a capacity of approximately 28,000 bpd, that transports crude oil from our tank farms in and around Longview, Texas and runs roughly parallel to the Nettleton Pipeline. While service on the East Texas Crude Logistics System may otherwise constitute transportation in interstate commerce and may be subject to the common carrier regulation and jurisdiction of FERC, it is currently subject to a temporary waiver issued by FERC on October 23, 2012, waiving the otherwise applicable tariff filing and reporting requirements for common carrier interstate service providers (the “East Texas Waiver Order”). The continuing effectiveness

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of the East Texas Waiver Order depends upon the continuation in effect of the following conditions: (1) our affiliates continuing to own 100% of the throughput; (2) there being no demonstrated third party interest in shipping on the system; (3) our not anticipating any such interest materializing; and (4) there remaining no demonstrated opposition to the continuing effectiveness of the East Texas Waiver Order.

Our East Texas Crude Logistics System also includes five owned or leased crude oil storage terminals, at which we store crude oil owned by Delek for the Tyler Refinery. The LaGloria Station consists of two tanks with an active shell capacity of approximately 450,000 barrels. The Nettleton Station consists of five tanks with an active shell capacity of approximately 222,000 barrels. It is located on property that we lease from a third party, as described in more detail in Item 2, "Facilities." In addition to the active shell capacity, the Nettleton Station includes approximately 55,000 barrels of shell capacity that is currently not in service. The Bradford Station consists of two tanks with an active shell capacity of approximately 65,000 barrels. The Arp Station consists of two tanks with an active shell capacity of approximately 110,000 barrels. The Big Sandy Station consists of seven tanks with an active shell capacity of approximately 248,000 barrels.

The table below sets forth historical average daily throughput for the East Texas Crude Logistics System.

 
 
Average Daily Throughput (bpd)
 
 
Year Ended
 
 
 
 
December 31,
 
 
 
 
2016
 
2015
 
2014
East Texas Crude Logistics System (average bpd)
 
12,735

 
18,828

 
7,361

% of Tyler Refinery Crude Throughput
 
17.8
%
 
30.6
%
 
12.5
%
 
We have a pipelines and tankage agreement with Delek to provide throughput on the East Texas Crude Logistics System. However, in April 2013, a reconfigured pipeline system that is owned and operated by third parties began transporting crude oil to the Tyler Refinery from west Texas. Delek has a 10-year agreement, with an initial term expiring in 2023, with such third parties to transport a substantial majority of the Tyler Refinery’s crude oil requirements on this reconfigured pipeline system. As a result of the third parties' ability to transport crude oil on its reconfigured pipeline system directly to the Tyler Refinery, the crude oil supplied through the Nettleton and McMurrey Pipelines fell below the minimum aggregate throughput requirements of our pipelines and tankage agreement with Delek during the second quarter of 2013 and has remained below the minimum aggregate throughput requirements since that time. We expect crude oil volumes transported on our East Texas Crude Logistics System to continue to be below the minimum throughput requirement of 35,000 bpd for the foreseeable future. However, Delek is required under its commercial agreement with us, to pay us throughput fees in an amount equal to the fees it would pay were we to throughput 35,000 bpd, based on the per barrel fees in our agreement. The initial term of this agreement expires in November 2017. Delek has opted to renew the agreement for a subsequent five-year term, which expires in November 2022.
  
Tyler-Big Sandy Pipeline. The Tyler-Big Sandy Pipeline is essentially one pipeline link between the Tyler Refinery and the Partnership's terminal at Big Sandy, Texas that consists of the following two pipelines, which effectively connect at the Hopewell Station: (i) the Hopewell Pipeline, an approximately 13-mile pipeline with a capacity of approximately 26,000 bpd, which originates at the Tyler Refinery and terminates at the Hopewell Station, and (ii) the Big Sandy Pipeline, a 19-mile pipeline with a capacity of approximately 26,000 bpd, which originates at the Hopewell Station and terminates at the Big Sandy Terminal. The Big Sandy Terminal has 13 tanks with an aggregate shell capacity of approximately 177,000 barrels. Service on the Tyler-Big Sandy Pipeline is not provided for third parties, and is classified as private intrastate carrier service.
 
Tyler Tank Assets. The Tyler Tank Assets consist of 96 storage tanks and certain ancillary assets (such as pumps and piping) located at and adjacent to the Tyler Refinery with an aggregate shell capacity of approximately 2.0 million barrels.

El Dorado Tank Assets. The El Dorado Tank Assets consist of 158 storage tanks and certain ancillary assets (such as pumps and piping) located at and adjacent to the El Dorado Refinery with an aggregate shell capacity of approximately 2.5 million barrels.
 
Greenville-Mount Pleasant Pipeline and Greenville Storage Facility. The Greenville-Mount Pleasant Pipeline is a 76-mile pipeline, connecting the Greenville Storage Facility and the Mount Pleasant Terminal. The service provided on the Greenville-Mount Pleasant Pipeline is regulated by the Texas Railroad Commission, subject to a tariff on file with that Commission. The Greenville Storage Facility has four tanks with an aggregate shell capacity of approximately 330,000 barrels and is connected to the Explorer Pipeline System.

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North Little Rock Tanks. Our terminal in North Little Rock, Arkansas has five tanks with an aggregate shell capacity of approximately 180,000 barrels.
 
FTT Trucking Assets. We own 123 trucks and 205 trailers used to haul primarily crude oil and other products for third parties and Delek.

El Dorado Rail Offloading Racks. The El Dorado Rail Offloading Racks consist of two crude oil rail offloading racks, which are designed to receive up to 25,000 bpd of light crude oil or 12,000 bpd of heavy crude oil, or any combination of the two, delivered by rail to the El Dorado Refinery and related ancillary assets.

Tyler Crude Tank. The Tyler Crude Tank is a crude oil storage tank and certain ancillary assets located adjacent to the Tyler Refinery. The Tyler Crude Tank has approximately 350,000 barrels of shell capacity and primarily supports the Tyler Refinery.

Wholesale Marketing and Terminalling Segment

Our wholesale marketing and terminalling segment provides wholesale marketing and terminalling services to Delek’s refining operations and to independent third parties from whom we receive fees for marketing, transporting, storing and terminalling refined products and to whom we wholesale market refined products. In providing certain of these services, we take ownership of the products and are therefore exposed to market risks related to the volatility of refined product prices in our west Texas operations, which depend on many factors, including demand and supply of refined products in the west Texas market, the timing of refined product deliveries and downtime at refineries in the surrounding area. As of December 31, 2016, we generated revenue in our wholesale marketing and terminalling segment by (i) providing marketing services for the refined products output of the Tyler Refinery, (ii) engaging in wholesale activity at our Abilene and San Angelo, Texas terminals, as well as at terminals owned by third parties, whereby we purchase light products for sale and exchange to third parties, and (iii) providing terminalling services to independent third parties and Delek. See “—Commercial Agreements—Other Agreements with Third Parties—West Texas." Also see Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for a discussion of our material commercial agreements with Delek. The tables below show the operating results for the wholesale marketing and terminalling segment. For the years ended December 31, 2016, 2015 and 2014, we present the results for the period during which we owned the assets, as delineated in any notes accompanying the tables.

Wholesale Marketing
 
East Texas. Pursuant to a marketing agreement with Delek, we market 100% of the refined products output of the Tyler Refinery, other than jet fuel and petroleum coke. See Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for additional information. The following table sets forth the historical sales volumes under this marketing agreement.

 
 
 
Year Ended
 
 
 
 
 
December 31,
 
 
 
2016
 
2015
 
2014
Sales volumes (average bpd):
68,131
 
59,174
 
61,368

West Texas. In our west Texas marketing operations, we generate revenue by purchasing refined products from independent third-party suppliers and from Delek for sale and exchange to third parties at our San Angelo and Abilene, Texas terminals and at third-party terminals located elsewhere in Texas. Our terminals in Abilene and San Angelo, Texas are leased to Noble Petro, Inc. ("Noble Petro") pursuant to a terminal and pipeline lease and operating agreement for nominal consideration.








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We own approximately 104 miles of product pipelines in west Texas that connect our San Angelo and Abilene, Texas terminals to the Magellan Orion Pipeline. These pipelines are currently leased to Noble Petro until January 1, 2018. The following table provides the location of the Abilene and San Angelo terminals associated with our marketing activities and the number of tanks, their storage capacities, number of truck loading lanes and maximum daily available truck loading capacity for the year ended December 31, 2016.

Terminal Location
Number of Tanks
Active Aggregate Shell Capacity (bbls)
Number of Truck Loading Lanes
Maximum Daily Available Truck Loading Capacity (bpd)
Abilene, TX (1)
9

368,000

2

15,000

San Angelo, TX
5

93,000

2

15,000

     Total
14

461,000

4

30,000

            
(1) 
Excludes approximately 545,530 barrels of shell capacity that is out of service.

Substantially all of our product sales in west Texas are on a wholesale basis. A large portion of the petroleum products we sell in west Texas are purchased from Noble Petro. Under the terms of a supply contract with Noble Petro (the "Abilene Contract"), we have the right to purchase up to 20,350 bpd of petroleum products for sale at our San Angelo and Abilene, Texas terminals. See “—Commercial Agreements—Other Agreements with Third Parties—West Texas." We also purchase finished products from Delek and from other third parties.
 
The following table details the average aggregate daily number of barrels of refined products, and the margins associated with such products, that we sold in our west Texas wholesale operations for the periods indicated.

 
Year Ended
 
 
 
December 31,
 
 
 
2016
 
2015
 
2014
Throughput (average bpd)
13,257

 
16,357

 
16,707

Gross margin (in thousands)
$
6,929

 
$
7,984

 
$
28,174

Gross margin per barrel
$
1.43

 
$
1.35

 
$
4.67


Terminalling

We provide terminalling services for products to independent third parties and Delek through light products terminals we own in Nashville, Tennessee and to Delek, or certain third parties to whom Delek has assigned its rights, through our light products terminals in Memphis, Tennessee; Tyler, Texas; Big Sandy, Texas; Mount Pleasant, Texas; El Dorado, Arkansas; and North Little Rock, Arkansas. See Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for additional information pertaining to our material agreements. See "—Commercial Agreements—Delek's Crude Oil and Refined Products Supply and Offtake Arrangement" for a description of a third party's involvement in certain agreements.


10



The following table provides the locations of our refined product terminals associated with our terminalling activities and their storage capacities, number of truck loading lanes, average truck loading volume and maximum daily available truck loading capacity for the year ended December 31, 2016.

 
 
 
 
Maximum
 
 
 
 
Daily
 
 
Active
 
Available
 
 
Aggregate
Number of
Truck
 
 
Shell
Truck
Loading
 
Number
Capacity
Loading
Capacity
Terminal Location
of Tanks
(bbls)
Lanes
(bpd)
Big Sandy, TX (2)
 
 
3

25,000

Memphis, TN 
12

126,000

3

20,000

Nashville, TN (1)
10

128,000

2

15,000

Tyler, TX (2)
 
 
11

91,000

North Little Rock, AR (2)
 
 
2

17,100

El Dorado, AR (2)
 
 
3

35,000

Mount Pleasant, TX
7

175,000

3

10,000

     Total
29

429,000

27

213,100

                

(1) 
Excludes approximately 10,000 barrels of shell capacity that is currently not in service.
(2) 
See "—Pipelines and Transportation Segment—Tyler-Big Sandy Pipeline," "—Pipelines and Transportation Segment—Tyler Tank Assets," "—Pipelines and Transportation Segment—North Little Rock Tanks" and "—Pipelines and Transportation Segment—El Dorado Tank Assets," above for a discussion of the storage tanks associated with these terminals.

The table below sets forth historical average daily throughput for each of our terminals.

 
 
Year Ended
 
 
December 31,
 
 
2016
 
2015
 
2014
Throughput (average bpd):
 
 
 
 
 
 
  Big Sandy, TX
 
7,025

 
7,135

 
1,760

  Memphis, TN
 
7,982

 
7,616

 
9,616

  Nashville, TN
 
6,939

 
9,440

 
6,376

  Tyler, TX
 
70,444

 
61,051

 
61,501

  El Dorado, AR (1)
 
17,040

 
10,363

 
9,807

  North Little Rock, AR
 
10,174

 
9,853

 
7,324

  Mount Pleasant, TX (2)
 
2,746

 
1,056

 
417

Total (average bpd)
 
122,350

 
106,514


96,801

    
(1) 
Throughputs for the year ended December 31, 2014 are for the 324 days the Partnership owned the El Dorado Terminal in 2014.
(2) 
Throughputs for the year ended December 31, 2014 are for the 92 days the Partnership operated the Mount Pleasant Terminal in 2014.


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Commercial Agreements

Commercial Agreements with Delek

The Partnership has a number of long-term, fee-based commercial agreements with Delek under which we provide various services, including crude oil gathering and crude oil, intermediate and refined products transportation and storage services, and marketing, terminalling and offloading services to Delek. Most of these agreements have an initial term ranging from five to ten years, which may be extended for various renewal terms at the option of Delek. These agreements typically include minimum quarterly volume, revenue or throughput commitments. Fees under each agreement are payable to us monthly by Delek or certain third parties to whom Delek has assigned certain of its rights. For a discussion of a third party's involvement in certain agreements, see "Delek's Crude Oil and Refined Products Supply and Offtake Arrangement." In most circumstances, if Delek or the applicable third party assignee fails to meet or exceed the minimum volume, throughput or other commitment during any calendar quarter, Delek, and not any third party assignee, will be required to make a quarterly shortfall payment to us equal to the volume or amount of the shortfall multiplied or increased by the applicable fee, subject to certain exceptions as specified in the applicable agreement. Carry-over of any volumes or revenue in excess of such commitment to any subsequent quarter is not permitted.

The tariffs and throughput and storage fees under our agreements with Delek are subject to increase or decrease annually, by the amount of any change in various inflation-based indices, including the FERC oil pipeline index, 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 Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for a complete discussion of our material commercial agreements with Delek.

Other Agreements with Delek

In addition to the commercial agreements described above, the Partnership has entered into the following agreement with Delek:

Omnibus Agreement. The Partnership entered into an omnibus agreement with Delek, our general partner, Delek Logistics Operating LLC ("OpCo") 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, as amended, the "Omnibus Agreement"). The Partnership entered into an amendment to the Omnibus Agreement on August 3, 2015, with an effective date of April 1, 2015. This amendment eliminated a $1.0 million per event deductible that applied to certain asset failures before Delek was required to reimburse the Partnership.

Other Agreements with Third Parties

Paline Pipeline System Capacity Reservation. We previously had separate agreements with two unrelated third parties for such parties to reserve certain capacity on the Paline Pipeline System. Pursuant to the terms of these agreements, each unrelated third party paid a fixed monthly fee for the exclusive right to use its respective reserved capacity on the pipeline, which together accounted for a combined 35,000 bpd. The initial term of each agreement ran through June 30, 2016. We extended one of the agreements through December 31, 2016, for a total reservation of 10,000 bpd. We currently maintain a tariff on file with the FERC for service provided on the Paline Pipeline System, which allows for third parties to ship on the available capacity of the pipeline.

West Texas. In our west Texas marketing operations, we generate revenue by purchasing refined products from independent third-party suppliers and Delek for sale and exchange to third parties at our San Angelo and Abilene, Texas terminals and at third-party terminals located elsewhere in Texas. Substantially all of our product sales in west Texas are on a wholesale basis. The majority of the petroleum products we sell in west Texas are purchased from Noble Petro. Under the terms of the Abilene Contract with Noble Petro, we have the right to purchase up to 20,350 bpd of petroleum products. Under this contract, we purchase petroleum products based on monthly average prices from Noble Petro immediately prior to our resale of such products to customers at our San Angelo and Abilene, Texas terminals, which we lease to Noble Petro. Under this arrangement, we have limited direct exposure to risks associated with fluctuating prices for these refined products due to the short period of time between the purchase and resale of these refined products. The Abilene Contract expires in December 2017 and does not have a renewal option. However, we also purchase finished products from Delek and from other third parties.

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Delek's Crude Oil and Refined Products Supply and Offtake Arrangement

Pursuant to an arrangement with Delek and Lion Oil, to which we are not a party, J. Aron acquires and holds either title to or a lien on substantially all crude oil and refined products transported on our Lion Pipeline System and SALA Gathering System. J. Aron is therefore considered the shipper for the liquid it owns on the Lion Pipeline System and the SALA Gathering System. J. Aron also has title to the refined products stored at our Memphis, North Little Rock and El Dorado terminals and in the El Dorado Storage Tanks. Under (i) our pipelines and storage agreement with Lion Oil relating to the Lion Pipeline System and the SALA Gathering System, (ii) our terminalling agreements with Lion Oil relating to the Memphis and North Little Rock terminals, and (iii) our throughput and tankage agreement relating to the El Dorado Terminal and Tank Assets, Lion Oil has assigned to J. Aron certain of its rights under these agreements, including the right to have J. Aron's crude oil and intermediate and refined products stored in or transported on or through these systems, the Memphis and North Little Rock terminals and the El Dorado Terminal and Tank Assets, with Lion Oil acting as J. Aron's agent for scheduling purposes. Accordingly, even though this is effectively a financing arrangement for Delek whereby J. Aron sells the product back to Delek, J. Aron is technically our primary customer under each of these agreements. J. Aron will retain these storage and transportation rights for the term of its arrangement with Delek and Lion Oil and J. Aron will pay us for the transportation, throughput and storage services we provide to it. The rights assigned to J. Aron will not alter Lion Oil's obligations to meet certain throughput minimum volumes under our agreements with respect to the transportation, throughputting and storage of crude oil and refined products through our facilities, but J. Aron's throughput will be credited toward Lion Oil's minimum throughput commitments. Accordingly, Lion Oil will be responsible for making any shortfall payments incurred under the pipelines and storage agreement or the terminalling agreement which may result from minimum throughputs or volumes not being met.

Customers

We are dependent upon Delek as our primary customer, and the loss of Delek as a customer would have a material adverse effect on both of our operating segments. We derive a substantial majority of our gross margin, which is defined as net sales less cost of goods sold, from fee-based commercial agreements with Delek or as a direct result of its operations. For more information pertaining to these agreements, please see "—Commercial Agreements." We also have other customers, including major oil companies, independent refiners and marketers, jobbers, distributors, utility and transportation companies and independent retail fuel operators.

Major Customers

Sunoco LP accounted for 10.5%, 16.2% and 23.3% of our total revenues for the years ended December 31, 2016, 2015 and 2014, respectively. Delek, directly or indirectly, accounted for 32.8%, 24.2% and 13.6% of our total revenues for the years ended December 31, 2016, 2015 and 2014, respectively. However, we believe that gross margin is a better measure of performance of our business than revenue, particularly in our wholesale marketing and terminalling segment, as total revenue varies with the price of the underlying product, such as a gallon of finished product. Accordingly, we believe that, for the purpose of evaluating our business on a customer-specific basis, gross margin is a more accurate indicator to reflect the importance of certain customers to our operations. Delek, directly or indirectly, accounted for 90.5%, 90.0%, and 76.6% of our gross margin for the years ended December 31, 2016, 2015 and 2014, respectively.

Competition

Pipelines and Transportation

Our business in this segment primarily consists of gathering, transporting and storing crude oil, intermediate and finished products for Delek and third parties, especially other refiners. We face competition for the transportation and storage of crude oil from other pipeline owners whose pipelines or storage facilities (i) may have a location advantage over our pipelines or storage facilities, (ii) may be able to transport or store more desirable crude oil or finished products to Delek or to third parties, (iii) may be able to transport or store crude oil or finished product at a lower rate, or (iv) may be able to store more crude oil or finished product. Any or all such factors could cause Delek, or our third-party customers, to reduce throughput to a level that is below the minimum throughput commitments established in any contracts we may have with them or determine not to renew such contracts when the term expires.

As a result of our physical integration with Delek's El Dorado Refinery, and our contractual relationships with Delek relative to the El Dorado Refinery, we do not believe that we will face significant competition for the transportation of crude oil or refined products to or from the El Dorado Refinery, particularly during the term of our Lion Pipeline System, SALA Gathering System, El Dorado Tank Assets

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and El Dorado Assets agreements with Delek. See Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for a discussion of our material commercial agreements with Delek.

Wholesale Marketing and Terminalling

The wholesale marketing and terminalling business is generally very competitive. Our owned refined product terminals, as well as the other third-party terminals we use to sell refined product, compete with other independent terminal operators as well as integrated oil companies on the basis of terminal location, price, versatility and services provided. The costs associated with transporting products from a loading terminal to end users usually limit the geographic size of the market that can be served economically by any terminal. Two key markets in west Texas that we serve from our owned facilities are Abilene and San Angelo, Texas. We have direct competition from an independent refinery that markets through another terminal in the Abilene market. However, there are no competitive fuel loading terminals within approximately 90 miles of our San Angelo terminal. Our Nashville terminal competes with a significant number of other terminals located in the greater Nashville area. With respect to terminalling services we provide to Delek at our Memphis and North Little Rock terminals, as a result of our exclusive terminalling agreements, we do not believe we will face significant competition from third parties for these services.
 
Pursuant to an exclusive marketing agreement with Delek, the term of which currently expires in 2026, we market 100% of the refined products output of the Tyler Refinery (other than jet fuel and petroleum coke). As a result, we do not believe that we will face significant competition for these services from third parties. In addition, as a result of our physical integration with the Tyler Refinery and our contractual relationships with Delek relative to the Tyler Refinery, we do not believe that we will face significant competition for the storage or throughput of intermediate or refined products at the Tyler Refinery, particularly during the term of our agreements with Delek. See Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for additional information. Should Delek's wholesale customers, however, reduce their purchases of refined products due to the increased availability of more competitively priced products from other suppliers or for other reasons, the volumes we sell under the aforementioned agreement could decrease below the minimum volume commitment under the contract. Delek's Tyler Refinery is the only full-range product supplier within 100 miles; therefore, we believe its location gives the Tyler Refinery a natural advantage over more distant competitors.
 

Governmental Regulation and Environmental Matters

Rate Regulation of Petroleum Pipelines

The rates and terms and conditions of service on certain of our pipelines are subject to regulation by the FERC under the Interstate Commerce Act (“ICA”) and by the state regulatory commissions in the states in which we transport crude oil, intermediate and refined products, including the Railroad Commission of Texas, the Louisiana Public Service Commission and the Arkansas Public Service Commission. Certain of our pipeline systems are subject to such regulation and have filed tariffs with the appropriate authorities. We also comply with the reporting requirements for these pipelines. Other of our pipelines have received a waiver from application of the FERC's tariff requirements, but comply with other applicable regulatory requirements.

The FERC regulates interstate transportation under the ICA, the Energy Policy Act of 1992 and the rules and regulations promulgated under those laws. The ICA and its implementing regulations require that tariff rates for interstate service on oil pipelines, including pipelines that transport crude oil, intermediate and refined products in interstate commerce (collectively referred to as “petroleum pipelines”), be just and reasonable and non-discriminatory and that such rates and terms and conditions of service be filed with the FERC. Under the ICA, shippers may challenge new or existing rates or services. The FERC is authorized to suspend the effectiveness of a challenged rate for up to seven months, though rates are typically not suspended for the maximum allowable period. Tariff rates are typically contractually subject to increase or decrease on July 1 of each year, by the amount of any change in various inflation-based indices, including the FERC oil pipeline index, 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. In addition, on October 20, 2016, FERC issued an Advance Notice of Proposed Rulemaking on Revisions to Indexing Policies and Page 700 of FERC Form No. 6, which could, if final rules are implemented as proposed, increase reporting burdens on interstate liquids transportation providers and, in some cases, prohibit pipelines, including ours, from increasing rates even if warranted by the annual index. See Item 1A, "Risk Factors—Risks Relating to Our Business."


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While the FERC regulates rates for shipments of crude oil or refined products in interstate commerce, state agencies may regulate rates and service for shipments in intrastate commerce. We own pipeline assets in Texas, Arkansas, and Louisiana; accordingly such assets may be subject to additional regulation by the applicable governmental authorities in those states. Without limitation, certain of our pipeline assets in Texas are operated under Texas Railroad Commission regulation and subject to filed tariffs with that agency. See Item 1, "Business—Pipelines and Transportation—Greenville-Mount Pleasant Pipeline and Greenville Storage Facility" for additional information on these tariffs. In Texas, a pipeline, with some exceptions, is required to operate as a common carrier by publishing tariffs and providing transportation without discrimination. Arkansas provides that all intrastate oil pipelines are common carriers. In Louisiana, all pipelines conveying petroleum from a point of origin within the state to a destination within the state are declared common carriers. The Louisiana Public Service Commission is empowered with the authority to establish reasonable rates and regulations for the transport of petroleum by a common carrier, mandating public tariffs and providing of transportation without discrimination. State commissions have generally not been aggressive in regulating common carrier pipelines, have generally not investigated the rates or practices of petroleum pipelines in the absence of shipper complaints and generally resolve shipper complaints informally.

Whether a pipeline provides service in interstate commerce or intrastate commerce is highly fact-dependent and determined on a case-by-case basis. We cannot provide assurance that the FERC will not at some point assert that some or all of the transportation service we provide, for which we do not have a tariff on file at the FERC, is within its jurisdiction. If the FERC were successful with any such assertion, the FERC's ratemaking methodologies may subject us to potentially burdensome and expensive operational, reporting and other requirements. Service on the East Texas Crude Logistics System is currently subject to a temporary waiver issued by FERC, as discussed above in Item 1, "Business—Pipelines and Transportation—East Texas Crude Logistics System." If the conditions to the continued effectiveness of that East Texas Waiver Order are no longer true at any point, service on that system would become fully subject to FERC tariff filing requirements and other regulatory requirements for the provision of transportation service.

Department of Transportation

The PHMSA of the United States Department of Transportation ("DOT") regulates the design, construction, testing, operation, maintenance, reporting and emergency response of crude oil, petroleum products and other hazardous liquids pipelines and other facilities, including certain tank facilities used in the transportation of such liquids. These requirements are complex, subject to change and, in certain cases, can be costly to comply with. We believe our operations are in substantial compliance with these regulations, but cannot assure you that substantial expenditures on our part will not be required to remain in compliance. Moreover, certain of these rules are difficult to insure adequately, and we cannot assure you that we will have adequate insurance to address costs and damages from any noncompliance.
 
The United States Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 (or Pipeline Safety Act) was enacted on January 3, 2012, pursuant to which the maximum civil penalties for certain violations were increased from $100,000 to $200,000 per violation per day and from a total cap of $1 million to $2 million. A number of the provisions of the Pipeline Safety Act have the potential to cause owners and operators of pipeline facilities to incur significant capital expenditures and/or operating costs. We intend to work closely with our industry associations to participate with and monitor DOT-PHMSA's efforts.

In January 2017, PHMSA finalized a new regulation that, once effective, will impose additional responsibilities concerning the operation, maintenance, and inspection of hazardous liquid pipelines; the reporting of pipeline incidents; reference standards for in-line pipeline inspection and the direct assessment of stress corrosion cracking; and other requirements. We are reviewing the new regulations and intend to adjust our operations, to the extent necessary, in order to comply with the regulations upon their effective date.

The DOT has issued guidelines with respect to securing regulated facilities against terrorist attack. We have instituted security measures and procedures in accordance with such guidelines to enhance the protection of certain of our facilities. We cannot provide any assurance that these security measures would fully protect our facilities from an attack.

The Federal Motor Carrier Safety Administration of the DOT regulates safety standards and monitors drivers and equipment of commercial motor carrier fleets. Such standards include vehicle and maintenance inspection requirements, limitations on the number of hours drivers may operate vehicles and financial responsibility requirements. We believe that the operations of our fleet of crude oil and finished products truck transports are substantially in compliance with these regulations and safety requirements.


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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, the remediation of contamination and the protection of workers and the public. Compliance with 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 or judicial authorities. The recent legislative and regulatory trend has been to place increasingly stringent restrictions and limitations on activities that may affect the environment; however, the impact of the change in administration on future changes to environmental laws and regulations remains uncertain. 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, 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, 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. See "—Hazardous Substances and Waste" below for additional information on regulations pertaining to releases into the environment. 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.

Indemnification

Under the Omnibus Agreement, Delek has agreed to indemnify us for certain environmental matters associated with the ownership of our assets as specified therein, including matters arising from operations by Delek, at or before the time of our acquisition of these assets from Delek.

Air Emissions and Climate Change

Our operations are subject to the Clean Air Act and its regulations and comparable state and local statutes. Under these laws, permits may be required before construction can commence on a new source of potentially significant air emissions, and operating permits may be required for sources that are already constructed. These permits may require controls on our air emission sources, and we may become subject to more stringent regulations requiring the installation of additional emission control technologies. Any such future obligations may require us to incur significant additional capital or operating costs. These air emissions requirements also affect Delek's refineries, from which we receive a substantial portion of our revenues. In the future, Delek may be required to incur significant capital expenditures to comply with new legislative and regulatory requirements relating to its operations. To the extent these capital expenditures have a material effect on Delek, they could have a material effect on our business and results of operations.

On May 15, 2012, EPA rules took effect that subject oil and natural gas operations, including production, processing, transmission and storage to regulation under the New Source Performance Standards (NSPS) and National Emission Standards for Hazardous Air Pollutants (NESHAP) programs. The finalized regulations establish specific new requirements for emissions from compressors, controllers, dehydrators, storage tanks, gas processing plants and certain other equipment. The EPA recently finalized updates to new source performance standard requirements that took effect August 2, 2016 that impose more stringent controls on methane and volatile organic compounds emissions from oil and gas development and production operations. These rules do not directly apply to our operations and we do not expect them to have a significant impact on our business.


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On October 23, 2015, the EPA published as a final rule the Clean Power Plan, which sets performance rates for GHG emissions from power generating units firing coal, oil or natural gas. While we do not operate power plants governed by this final rule, it remains unclear what impact the rule may have on demand for oil, coal, natural gas and renewable energy sources, including crude oil and refined products transported and stored by us. These and other GHG-related requirements that disproportionately affect the cost of energy from oil in comparison to competing energy sources could affect demand for our services. The U.S. Supreme Court has stayed the Clean Power Plan final rule until pending legal challenges are resolved. Although the outcome of these legal challenges remains uncertain, with the change in the administration, the Clean Power Plan rule is not currently expected to be implemented.

Renewable Fuel Standard

The Energy Independence and Security Act of 2007 ("EISA") was enacted into federal law in December 2007 creating the Renewable Fuel Standard - 2 (RFS-2) rule, requiring the amounts of renewable fuel sold or introduced in the United States to reach 36 billion gallons by 2022. The EPA has finalized volume requirements for 2017, however, the requirements remain subject to review by the current administration. Additionally, the EPA has the ability to alter the annual blending requirements. Although Delek’s refineries are obligated parties under this rule, our entities are not obligated parties and have no requirement to blend specific volumes of renewable fuels. However, the requirements could reduce future demand for petroleum products and thereby have an indirect effect on certain aspects of our business, although it could increase demand for our ethanol and biodiesel fuel blending services at our truck loading racks.

Hazardous Substances and Waste

To a large extent, the environmental laws and regulations affecting our operations relate to the release of hazardous substances or solid wastes into water or soils, and include measures to control pollution of the environment. These laws generally regulate the generation, storage, treatment, transportation and disposal of solid and hazardous waste. They also require corrective action, including investigation and remediation, at a facility where such waste may have been released or disposed. For instance, the Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA"), which is also known as Superfund, and comparable state laws, impose liability without regard to fault or to the legality of the original conduct, on certain classes of persons that contributed to the release of a “hazardous substance” into the environment. These persons include the owner or operator of the site where the release occurred and companies that disposed of, or arranged for the disposal of, the hazardous substances found at the site. Under CERCLA, these persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. In the course of our ordinary operations, we generate waste that falls within CERCLA’s definition of a “hazardous substance” and, as a result, may be jointly and severally liable under CERCLA for all or part of the costs required to clean up certain sites.

We also generate small quantities of solid wastes, including hazardous wastes that are subject to the requirements of the federal Resource Conservation and Recovery Act ("RCRA"), and comparable state laws. From time to time, the EPA considers the adoption of stricter disposal standards for non-hazardous wastes, including crude oil and refined products wastes. We are not currently required to comply with a substantial portion of the RCRA requirements, because our operations generate minimal quantities of hazardous wastes. However, it is possible that additional wastes, which could include wastes currently generated during operations, will in the future be designated as “hazardous wastes.” Hazardous wastes are subject to more rigorous and costly disposal requirements than are non-hazardous wastes. Any changes in the regulations could increase our, and our competitors’, maintenance capital expenditures and operating expenses.

We currently own and lease, and Delek has in the past owned and leased, properties where hydrocarbons are being or have been handled for many years. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons or other waste may have been disposed of or released on or under the properties owned or leased by us or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes were not under our control. These properties and wastes disposed thereon may be subject to CERCLA, RCRA, and analogous state laws. Under these laws, we could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) or to perform remedial operations to prevent future contamination.


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Water

Our operations can result in the discharge of pollutants, including crude oil and refined products. Several of our pipelines and terminals are located near, or cross under or over, environmentally sensitive waters, such as streams, creeks, rivers, lakes and wetlands. The transportation and storage of crude oil and refined products over and adjacent to water involves risk and subjects us to the provisions of the Oil Pollution Act of 1990 (the "OPA"), the Water Pollution Control Act of 1972 (the "Clean Water Act") and related state requirements. These requirements subject owners of covered facilities to strict, joint and potentially unlimited liability for containment and removal costs, natural resource damages and certain other consequences of an oil spill where the spill is into navigable waters, along shorelines or in the exclusive economic zone of the United States. In the event of an oil spill into navigable waters, substantial liabilities could be imposed upon us. States in which we operate have also enacted similar and, in some cases, more stringent laws.

Regulations under the Clean Water Act, the OPA and state laws also impose additional regulatory burdens on our operations. Spill prevention control and countermeasure requirements of federal laws and some state laws require containment to mitigate or prevent contamination of navigable waters in the event of an oil overflow, rupture or leak. For example, the Clean Water Act requires us to maintain spill prevention control and countermeasure plans at many of our facilities. In addition, the OPA requires that most oil transport and storage companies maintain and update various oil spill prevention and oil spill contingency plans. We maintain such plans, and where required have submitted plans and received federal and state approvals necessary to comply with the OPA, the Clean Water Act and related regulations. We regularly review and modify our crude oil and refined product spill prevention plans and procedures to help prevent crude oil and refined product releases and to minimize potential impacts should a release occur.

The Clean Water Act also imposes restrictions and strict controls regarding the discharge of pollutants into navigable waters. Our facilities contract with third parties for wastewater disposal, discharge to local Publicly Owned Treatment Works (POTW), or discharge under the terms of a National Pollutant Discharge Elimination System (NPDES) permit for wastewater and stormwater. In the event regulatory requirements change, or interpretations of current requirements change, and our facilities are required to undertake different wastewater management arrangements, we could incur substantial additional costs. The Clean Water Act imposes substantial potential liability for the violation of permits or permitting requirements and for the costs of removal, remediation, and damages resulting from such discharges. In addition, some states maintain groundwater protection programs that require permits for discharges or operations that may impact groundwater conditions.

Employees

We have no employees. Rather, all of the employees that conduct our business are employed by our general partner and its non-Partnership affiliates, and we believe that our general partner and its non-Partnership affiliates have a satisfactory relationship with those employees.

Seasonality and Customer Maintenance Programs

The volume and throughput of crude oil 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 of such products in the markets served directly or indirectly by our assets. 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. While demand for asphalt products, which are a substantial portion of the El Dorado Refinery's product mix, is also lower in the winter months. In addition, our refining customers, such as Delek, occasionally reduce or suspend operations to perform planned maintenance, which is more typically scheduled 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.

Available Information

Our internet website address is www.DelekLogistics.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to such reports filed with (or furnished to) the Securities and Exchange Commission (“SEC”) are available on our internet website (in the “Investor Relations” section) free of charge, as soon as reasonably practicable after we file or furnish such material to the SEC. We also

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post our corporate governance guidelines, code of business conduct and ethics and the charter of the audit committee of the board of directors of our general partner in the same website location. Our governance documents are available in print to any unitholder that makes a written request to Secretary, Delek Logistics, GP, LLC, general partner of Delek Logistics Partners, LP, 7102 Commerce Way, Brentwood, TN 37027.

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ITEM 1A.  RISK FACTORS

Limited partner interests are inherently different from shares of capital stock of a corporation, although many of the business risks to which we are subject are similar to those that would be faced by a corporation engaged in similar businesses. If any of the following risks were to occur, our business, financial condition or results of operations could be materially and adversely affected. In that case, we might not be able to pay the minimum quarterly distribution on our common units or the trading price of our common units could decline.

Risks Relating to Our Business

Delek, directly or indirectly, accounts for a substantial majority of our gross and contribution margins. Therefore, we are indirectly subject to the business risks of Delek. If Delek changes their business strategy, fails to satisfy their obligations under our commercial agreements for any reason or significantly reduces the volumes transported through our pipelines or handled at our terminals or its use of our marketing services, then our revenues, and, consequently, our margins would decline and our financial condition, results of operations, cash flows and ability to make distributions to our unitholders could be adversely affected.

Delek, directly or indirectly, accounted for 90.5%, 90.0% and 76.6% of our gross margin for the years ended December 31, 2016, 2015 and 2014, respectively, and is the only customer for a substantial majority of our assets. In addition, Delek is, effectively, through its supply and offtake agreement with its assignee, the principal customer for our Lion Pipeline System, our SALA Gathering System and our El Dorado, Memphis and North Little Rock terminals. Please see "Item 1- Business - Delek's Crude Oil and Refined Products Supply and Offtake Arrangement." As we expect to continue to derive the substantial majority of our margins from Delek, either directly or indirectly, for the foreseeable future, we are subject to the risk of nonpayment, nonperformance or underperformance by Delek under our commercial agreements. In addition, we are subject to the risk of nonpayment, nonperformance or underperformance by Delek’s assignees. If Delek were to significantly decrease, or cause the significant decrease of, the materials transported on our pipelines or the volumes of refined products handled at our terminals, whether because of business or operational difficulties or strategic decisions by Delek’s management, it is unlikely that we would be able to utilize any additional capacity on our pipelines or terminal facilities to service third-party customers without substantial capital outlays and delays, if at all, which could materially and adversely affect our results of operations, financial condition and cash flows. Likewise, the terms of Delek's obligations under its agreements with us are for initial terms ranging from five years to ten years, with options to extend at the election of Delek. The initial terms for some of these agreements expire in November 2017. Delek has opted to renew these agreements for subsequent five-year terms. However, there are numerous other agreements with Delek that are not yet eligible for renewal. If Delek fails to renew these contracts as they come up for renewal, or if Delek fails to use our assets and services after the expiration of the agreements, or should our agreements be invalidated for any reason, and we are unable to generate revenue from third parties with respect to such assets, we could be materially and adversely affected. See Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K, for a complete discussion of our material commercial agreements with Delek. Additionally, any event, whether in our areas of operation or otherwise, that materially and adversely affects Delek’s or its assignees' operations, financial condition, results of operations or cash flows may adversely affect us and our business and, therefore, our ability to sustain or increase cash distributions to our unitholders. Accordingly, we are indirectly subject to the operational and business risks of Delek and its assignees, including, but not limited to, the following:

the timing and extent of changes in the costs and availability of crude oil and other refinery feedstocks (including prolonged periods of low crude oil prices that could impact production of inland crude oil and reduce the amount of cost advantaged crude oil available and/or the discount of such crude oil as compared to other crude oil) and in the price and demand for Delek's refined products;
the risk of contract cancellation, non-renewal or failure to perform by Delek’s suppliers or customers, and Delek’s inability to replace such suppliers, contracts, customers and/or revenues;
disruptions due to equipment interruption or failure or other events at Delek’s facilities, or at third-party facilities on which Delek’s business is dependent;
the effects of economic downturns on Delek’s business and the business of its suppliers, customers, business partners and lenders;
Delek’s ability to remain in compliance with its contracts;
Delek’s ability to remain in compliance with the terms of its outstanding and any future indebtedness;
changes in the cost or availability of third-party pipelines, terminals and other means of delivering and transporting crude oil, feedstocks and refined products;
state and federal environmental, economic, health and safety, energy and other policies and regulations, and any changes in those policies and regulations;
environmental incidents and violations and related remediation costs, fines and other liabilities; and
changes in crude oil and refined product inventory levels and carrying costs.


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Additionally, Delek continually considers opportunities presented by third parties with respect to its refinery assets. These opportunities may include offers to purchase certain assets and joint venture propositions. Delek may also change its refineries’ operations by constructing new facilities, suspending or reducing certain operations, or modifying or closing facilities. Changes may be considered to meet market demands, to satisfy regulatory requirements or environmental and safety objectives, to improve operational efficiency or for other reasons. Delek actively manages its assets and operations, and, therefore, changes of some nature, possibly material to its business relationship with us, could occur in the future.

Furthermore, conflicts of interest may arise between Delek and its affiliates, including our general partner, on the one hand, and us and our unitholders, on the other hand. We have no control over Delek or our general partner, and Delek may elect to pursue a business strategy or make other decisions that do not favor us or our business. Please see “—Risks Relating to Our Partnership Structure—Our general partner and its affiliates, including Delek, have conflicts of interest with us and limited duties to us and our unitholders, and they may favor their own interests to the detriment of us and our other common unitholders.”

Our operations and Delek’s refining operations, some of which have been in service for decades, are subject to many risks and operational hazards, for which we may not be adequately insured, some of which may result in business interruptions and shutdowns of our or Delek’s facilities and liability for damages. If a significant accident or event occurs that results in a business interruption or shutdown, our operations and financial results could be adversely affected.

Our operations are subject to all of the risks and operational hazards inherent in gathering, transporting and storing crude oil and intermediate and refined and other products, including:

business interruption due to maintenance and repairs or mechanical or structural failures with respect to our assets, or our facilities or with respect to third-party assets or facilities on which our operations are dependent, including Delek’s assets or facilities;
operational errors that result in a loss of physical integrity or performance in our pipelines and facilities;
deterioration of the condition of our pipelines and facilities through age, use and disuse;
damages to our assets and surrounding properties caused by earthquakes, floods, fires, severe weather, explosions and other natural disasters and acts of terrorism;
damages to and loss of availability of interconnecting third-party pipelines, terminals and other means of delivering crude oil, feedstocks and refined petroleum products;
the inability of third-party facilities on which our operations are dependent, including Delek’s facilities, to complete capital projects and to restart timely refining operations following a shutdown;
curtailments of operations as a result of severe seasonal weather;
inadvertent damage to pipelines from construction, farm and utility equipment;
constrained pipeline and storage infrastructure;
disruption or failure of information technology systems and network infrastructure due to various causes, including unauthorized access or attacks; and
other hazards.

These risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property and equipment and pollution or other environmental damage, as well as business interruptions or shutdowns of our assets and facilities. Any such event or unplanned shutdown could have a material adverse effect on our business, financial condition and results of operations. In addition, Delek’s refining operations, on which our operations are substantially dependent and over which we have no control, are subject to these and other operational hazards and risks inherent in refining crude oil. A significant accident or event, such as described above at Delek’s facilities, could damage our assets, expose us to significant liability and could affect Delek’s ability and/or obligation to satisfy the minimum volume commitments under our commercial agreements with Delek, any of which could have a material adverse effect on our business, financial condition and results of operations.

Further, significant portions of our pipeline systems, including our gathering system, and storage and terminalling facilities have been in service for many decades, which could enhance the risks and operational hazards discussed above. The age and condition of our systems could also result in increased maintenance or repair expenditures, and any downtime associated with increased maintenance and repair activities could materially reduce our revenue. Any significant increase in maintenance and repair expenditures or loss of revenue due to the age or condition of our systems could adversely affect our business and results of operations and our ability to make cash distributions to our unitholders.


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Our insurance policies and other contractual protections from Delek do not cover all losses, costs or liabilities that we may experience, and insurance companies that currently insure companies in the energy industry may cease to do so or substantially increase premiums.

We are insured under the property, liability and business interruption insurance policies of Delek, subject to the deductibles and limits under those policies. To the extent Delek experiences losses under the insurance policies, the limits of our coverage may be decreased. In addition, we are not insured against all potential losses, costs or liabilities. We could suffer losses for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. In addition, because Delek’s business interruption policy does not cover losses for the first 21, 30, 45 or 60 days of the interruption, depending on the facility covered, a significant part, or all, of a business interruption loss could be uninsured. The occurrence of an event that is not fully covered by insurance could have a material adverse effect on our business, financial condition and results of operations.

The energy industry is highly capital intensive, and the entire or partial loss of individual facilities or multiple facilities can result in significant costs to both energy industry companies, such as us, and their insurance carriers. Large energy industry claims could result in significant increases in the level of premium costs and deductibles for participants in the energy industry. Insurance companies that have historically participated in underwriting energy-related facilities may discontinue that practice, may reduce the insurance coverage they are willing to offer or demand significantly higher premiums or deductibles. If significant changes occur in the number or financial solvency of insurance underwriters for the energy industry, or if other adverse conditions over which we have no control prevail in the insurance market, we may be unable to obtain and maintain adequate insurance at a reasonable cost.

Furthermore, any loss under the insurance policies experienced by Delek may impact our ability to obtain, renew or arrange for adequate alternative coverage. The unavailability of full insurance coverage to cover events in which we suffer significant losses could have a material adverse effect on our business, financial condition and results of operations.

Under the Omnibus Agreement, Delek has also agreed to reimburse us for certain losses related to certain asset failures, which provisions expire at various times depending on the asset involved. See Item 1, "Business—Commercial Agreements—Other Agreements with Delek—Omnibus Agreement." However, upon such expiration, or if Delek were to default under the Omnibus Agreement or otherwise fail to satisfy its obligations to us and insurance coverage was not otherwise available or was otherwise available only at substantial retention levels or cost, we could suffer significant losses that could have a material adverse effect on our business, financial condition and results of operations.

If we are unable to generate sufficient cash flow, our ability to pay quarterly distributions to our common unitholders at all, at current levels or in an amount equal to the minimum quarterly distribution or our ability to increase our quarterly distributions in the future could be impaired materially.

Our ability to pay quarterly distributions (including distributions equal to, or in excess of, the minimum quarterly distribution) depends primarily on cash flow, including cash flow from operations, cash from financial reserves, cash from credit facilities and cash from the capital markets, and not solely on profitability, which is affected by non-cash items. As a result, we may pay cash distributions during periods of losses and may be unable to pay cash distributions during periods of income. Our ability to generate sufficient cash flow is largely dependent on our ability to manage our business successfully, but may also be affected by economic, financial, competitive, regulatory and other factors beyond our control. For example, we may not be able to obtain debt or equity financing on terms that are favorable to us, if at all, and we may be required to fund our working capital requirements principally with cash generated by our operations and borrowings under our credit facilities and not to increase or pay distributions.

We may not have sufficient available cash each quarter to enable us to pay distributions at current levels or at the minimum quarterly distribution. In addition, even if we are able to make distributions in excess of the minimum quarterly distribution, because the cash we generate will fluctuate from quarter to quarter, quarterly distributions, or any period over period growth in such distributions, may also fluctuate, or even decrease, from quarter to quarter. Any failure to pay distributions at expected levels could result in a loss of investor confidence and a decrease in the trading price of our units.






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Our assets and operations are subject to federal, state and local laws and regulations relating to environmental protection, pipeline integrity and safety that could require us to make substantial expenditures. In addition, our business involves the risks of spills, releases and emissions from our facilities, which could require us to make substantial expenditures and subject us to fines and penalties.

Our assets and operations involve the transportation and storage of crude oil and products, which are subject to increasingly stringent and extensive federal, state and local laws and regulations related to the discharge and remediation of materials in the environment, greenhouse gas emissions, waste management, species and habitat preservation, pollution prevention, pipeline integrity and other safety-related regulations, and characteristics and composition of fuels. These laws and regulations require us to comply with various safety requirements regarding the design, installation, testing, construction and operational management of certain of our assets. These requirements have raised operating costs, and compliance with such laws and regulations may cause us to incur potentially material capital expenditures associated with the construction, maintenance and upgrading of equipment and facilities. Environmental laws and regulations, in particular, are subject to frequent change, and many of them have become and may continue to become more stringent.

Transportation and storage of crude oil and products involves inherent risks of spills and releases and emissions into the air from our facilities, and can subject us to various federal and state laws governing spills and releases, including reporting and remediation obligations. We have experienced multiple releases and spills from our facilities and are subject to ongoing remediation and/or monitoring projects. The costs associated with such obligations can be substantial, as can costs associated with related enforcement matters, including possible fines and penalties. Transportation of crude oil and products over water, or proximate to navigable bodies of water, involves inherent risks (including risks of spills) and could subject us to the provisions of the OPA, the Clean Water Act and similar state environmental laws should a spill occur from our facilities. See "Item 1-Business-Governmental Regulation and Environmental Matters-Water." Among other things, the OPA requires us to prepare a facility response plan identifying the personnel and equipment necessary to remove, to the maximum extent practicable, a “worst case discharge.” While our plans are designed to mitigate environmental impacts, such plans may not protect us from all liability associated with the discharge of crude oil or products into navigable waters.
 
With respect to the releases that have occurred, or for an event that occurs or is discovered in the future, whether in connection with any of our assets or any other facility to which we send or have sent waste or by-products for treatment or disposal, or a facility or assets that we may acquire from time to time as part of our ongoing growth strategy, we could be liable for all costs and penalties associated with the remediation of such facilities under federal, state and local environmental laws or common law. We may also be liable for personal injury, property damage and natural resource damage claims from third parties alleging contamination from spills or releases from our facilities or operations. In addition, even if we are insured against such risks, we may be responsible for costs or penalties to the extent our insurers do not fulfill their obligations to us or our insurance policies do not cover such items. Our failure to comply with these, or any other environmental, pipeline integrity or safety-related laws or regulations, could result in the assessment of administrative, civil or criminal penalties, the imposition of investigatory and remedial liabilities and the issuance of injunctions that may subject us to additional operational constraints. At present, the United States Department of Justice is evaluating an enforcement action on behalf of the Environmental Protection Agency with regard to potential Clean Water Act violations arising from the 2013 release at our Magnolia Station. See "Item 3- Legal Proceedings." In addition, we could incur potentially significant additional expenses should we determine that any of our assets are not in compliance with such laws or regulations in order to bring our assets into compliance. Any such expenses, penalties or liabilities could have a material adverse effect on our business, financial condition or results of operations. While we are entitled to reimbursement or indemnification from Delek for certain environmental liabilities under the Omnibus Agreement, such reimbursement or indemnification may not fully cover any damages we may incur, or Delek may default on or otherwise fail to satisfy its obligations to us, which could have a material adverse effect on our business, financial condition or results of operations.

Further, certain of our pipeline facilities are subject to the pipeline safety regulations of the PHMSA at the DOT. PHMSA regulates the design, construction, testing, operation, maintenance, reporting and emergency response of crude oil, petroleum products and other hazardous liquid pipeline facilities.
 
PHMSA has adopted regulations requiring pipeline operators to develop integrity management programs for hazardous liquids pipelines located where a leak or rupture could affect “high consequence areas” that are populated or environmentally sensitive areas, although recent rulemaking is extending certain requirements beyond high consequence areas. PHMSA has also issued regulations that subject certain rural low-stress hazardous liquids pipelines to the integrity management requirements. The integrity management regulations require operators, including us, to:

perform ongoing assessments of pipeline integrity;
identify and characterize applicable threats to pipeline segments that could impact a high consequence area;
maintain processes for data collection, integration and analysis;
repair and remediate pipelines as necessary; and
implement preventive and mitigating actions.


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PHMSA also carries out the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011, which increased penalties for safety violations, established additional safety requirements for newly constructed pipelines, imposed new emergency response and incident notification requirements and required studies of certain safety issues that could result in the adoption of new regulatory requirements for existing pipelines. The Protecting our Infrastructure of Pipelines and Enhancing Safety Act (the "PIPES Act") was finalized in 2016, reauthorizing PHMSA’s pipeline safety programs through 2019 and directing PHMSA to complete unfinished mandates of the 2011 Act. The PIPES Act also directs PHMSA to provide a report to Congress within eighteen months studying the risks and providing safety recommendations for existing hazardous liquid pipelines as well as giving the agency increased emergency order authority to shut down and restrict pipeline use for unsafe conditions or practices.

We may incur significant costs and liabilities associated with compliance with pipeline safety regulations, and any corresponding repair, remediation, preventive or mitigation measures required for our non-exempt pipeline facilities, including lost cash flows resulting from shutting down our pipelines during the pendency of such repairs. Moreover, changes to pipeline safety laws and regulations that result in more stringent or costly pipeline integrity management or safety standards could have a material adverse effect on us and similarly situated operators.

A material decrease in wholesale fuel margins or in the quantity of barrels sold to wholesale customers could adversely affect our financial condition, results of operations, cash flows and ability to service our indebtedness.

Our wholesale fuel sales in our west Texas business are made to third party customers. The margins we earn on these sales ,and the quantity of barrels we sell, are dependent on a number of factors outside our control, including the overall supply of refined products, overall market conditions, the demand for these products, competition from third parties, the price of ethanol and the value of renewable identification numbers ("RINs") we receive from blending renewable fuels. Specifically, among other circumstances, the margins we earn through these activities may be adversely impacted in the event of excess supply of refined products or decreased customer demand. These supply and demand dynamics are subject to day-to-day variability and may result in volatility in the margins that we achieve. These, and other dynamics, may also result in our customers reducing their purchases of product from us in favor of purchasing more product from other refiners or suppliers. Further, decreases in the value of RINs could impact our margins in our wholesale business. In addition, our margins are affected by the price we pay for ethanol, which is blended into certain refined products. We occasionally lock in ethanol prices by committing to purchase ethanol in the future at a certain price. If the spot price for ethanol at the time we actually take delivery of such product is less than what we paid for it, our margins could be negatively impacted. Extended periods of market conditions that result in us earning margins lower than anticipated or in us selling fewer barrels of product to wholesale customers, for any of the reasons set forth above or otherwise, could adversely affect our financial condition, results of operations and cash flows.
 
Our contract counterparties may suspend, reduce or terminate their obligations under our various commercial agreements in certain circumstances, including events of force majeure, which could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to unitholders.

Our commercial agreements with Delek and third parties provide that the counterparty may, depending on the commercial agreement, suspend, reduce or terminate its obligations to us under the applicable agreement, including the requirement to pay the fees associated with the applicable minimum volume commitments, in the event of (i) a material breach of the agreement by us, (ii) in the case of Delek, Delek deciding to permanently or indefinitely suspend refining operations at one or more of its refineries, or (iii) the occurrence of certain force majeure events that would prevent us or the third party from performing our or its obligations under the applicable agreement. Force majeure events may include any acts or occurrences that prevent services from being performed either by us or such third party under the applicable agreement, such as:

acts of God;
strikes, lockouts or other industrial disturbances;
acts of the public enemy, wars, blockades, insurrections, riots or civil disturbances;
storms, floods or washouts;
arrests or the order of any court or governmental authority having jurisdiction while the same is in force and effect;
explosions, breakage or accident to machinery, storage tanks or lines of pipe;
any inability to obtain, or unavoidable delay in obtaining, material or equipment;
any inability to deliver crude oil or refined products because of a failure of third-party pipelines; and
any other causes not reasonably within the control of the party claiming suspension and which by the exercise of due diligence such party is unable to prevent or overcome.

Our counterparties have the discretion in certain circumstances to decide to suspend, reduce or terminate their obligations under our commercial agreements notwithstanding the fact that their decisions may significantly and adversely affect us.


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Accordingly, there exists a broad range of events that could result in us being unable to utilize our assets, and Delek or its assignee or a third party, as the case may be, no longer having an obligation to meet its minimum volume commitments or pay the amounts otherwise owing under the applicable agreement. Furthermore, a single event relating to one of Delek’s refineries could have such an impact on multiple of our commercial agreements with Delek or its assignee. Any reduction, suspension or termination of any of our commercial agreements could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to unitholders.

If Delek satisfies only its minimum obligations under, or if we are unable to renew or extend, the various commercial agreements we have with Delek, our ability to make distributions to our unitholders may be impaired.

Delek is not obligated to use, or to pay us with respect to our services, for volumes of crude oil or refined products in excess of the minimum volume commitments under the various commercial agreements with us. During refinery turnarounds, which typically last 30 to 60 days and are performed every three to five years, and during other planned or unplanned maintenance periods, Delek may only satisfy its minimum volume commitments during such periods with respect to our assets that serve the refinery. In addition, the initial terms of Delek’s obligations under those agreements range from five to ten years, unless earlier terminated as described above, with Delek having the option to renew. If Delek fails to use our services for volumes of crude oil or refined products in excess of the minimum volume commitments or fails to use our facilities and services after expiration of those agreements, or if Delek terminates those agreements prior to their expiration, and we are unable to generate additional revenues from third parties, our ability to make cash distributions to unitholders may be impaired.

A material decrease in the refining margins at either of Delek’s refineries could materially reduce the volumes of crude oil or refined products that we handle, which could adversely affect our financial condition, results of operations, cash flows and ability to make distributions to unitholders.

The volumes of crude oil and refined products that we transport and refined products that we market depend substantially on Delek’s refining margins. Refining margins are dependent mostly upon the price of crude oil or other refinery feedstocks and the price of refined products. These prices are affected by numerous factors beyond our or Delek’s control, including the dynamics of global supply and demand for crude oil, gasoline and other refined products. The impact of low refined product demand may be further compounded by excess global refining capacity and high inventory levels.

If the demand for refined products, particularly in Delek’s primary market areas, decreases significantly, or if there were a material increase in the price of crude oil supplied to Delek’s refineries without an increase in the value of the refined products produced by those refineries, either temporary or permanent, which caused Delek to reduce production of refined products at its refineries, there would likely be a reduction in the volumes of crude oil and refined products we handle for Delek. Any such reduction could adversely affect our financial condition, results of operations, cash flows and ability to make distributions to our unitholders.

A material decrease in the supply of attractively priced crude oil could materially reduce the volumes of crude oil and refined products that we transport and store, which could materially and adversely affect our financial condition, results of operations, cash flows and ability to make distributions to our unitholders.

The volumes of crude oil and refined products that we may transport on our pipelines will depend on the volumes of crude oil processed and refined products produced at Delek’s refineries, as well as third parties' desire to transport crude on our systems, including our Paline Pipeline. The volumes of crude oil processed and refined products produced depend, in part, on the availability of attractively priced crude oil. For example, if a shipper on one of our pipeline systems is unable to locate or purchase attractively priced crude, which could happen due to a large number of market factors, and their shipments on our system are made in large part because of the pipeline's proximity to such attractively priced crude, then our pipeline may not be utilized. If the capacity of such pipeline is not under contract, or the pipeline is not utilized at all or to its capacity, then our results may be adversely affected. Our Paline Pipeline is such a pipeline. We previously had two separate agreements with unrelated third parties for such parties to reserve capacity of a combined 35,000 bpd on the Paline Pipeline; however, the term of each of these agreements has now expired. Since the capacity agreements on the Paline Pipeline have now expired, the Paline Pipeline may go unused or underused for a period of time, which could affect our operating results if third parties are no longer interested in transporting crude oil along that route for economic reasons associated with the price of crude or other reasons.

Further, in order to maintain or increase production levels at Delek’s refineries, Delek must continually contract for new crude oil supplies or consider connecting to alternative sources of crude oil. Adverse developments in major oil producing regions around the world could have a significant impact on our financial condition, results of operations and cash flows because of our lack of industry and geographic diversity and substantial reliance on Delek as a direct or indirect customer. Accordingly, in addition to risks related to accessing, transporting and storing crude oil and refined products, we are disproportionately exposed to risks inherent in the broader oil and gas industry, including:
 
the volatility and uncertainty of regional pricing differentials for crude oil and refined products;

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the ability of the members of the Organization of the Petroleum Exporting Countries, or OPEC, to agree to and maintain production controls;
the nature and extent of governmental regulation and taxation; and
the anticipated future prices of crude oil and refined products in markets served by Delek’s refineries.

If, as a result of any of these or other factors, the volumes of attractively priced crude oil available to Delek’s refineries are materially reduced for a prolonged period of time, the volumes of crude oil and refined products that we transport and store, and the related fees for those services, could be materially reduced, which could materially and adversely affect our financial condition, results of operations, cash flows and ability to make distributions to our unitholders.

A portion of our operations are conducted through joint ventures, over which we do not have full control and which have unique risks.

A portion of our operations are conducted through joint ventures, in which we have been making investments since 2015. We are able to appoint members to the managing boards of each of the joint ventures and maintain certain rights of approval over certain actions of our partners and/or their affiliates. However, our partners in each of our joint ventures, or their affiliates, serve as, or are responsible for, the contractor and the operator of the joint ventures' assets, and we have limited control over the same. In addition, we have limited control over the cash distribution policies of each of the joint ventures.

We share ownership in the joint ventures with partners that may not always share our goals and objectives. Differences in views among the partners may result in delayed decisions or failures to agree on major matters, such as large expenditures or contractual commitments, the construction of assets or borrowing money, among others. Delay or failure to agree may prevent action with respect to such matters, even though such action may not serve our best interest or that of the joint venture. Accordingly, delayed decisions and disagreements could adversely affect the business and operations of the joint ventures and, in turn, our business and operations. From time to time, our joint ventures may be involved in disputes or legal proceedings which may negatively affect our investments. Accordingly, any such occurrences could adversely affect our financial condition, operating results and cash flows.

Our substantial dependence on Delek's Tyler and El Dorado Refineries, as well as the lack of diversification of our assets and geographic locations, could adversely affect our ability to make distributions to our common unitholders.

We believe that a substantial majority of our gross and contribution margins for the foreseeable future will be derived from the operation of our pipelines, gathering systems and terminal and storage facilities that support the Tyler and El Dorado Refineries and are primarily located in Arkansas and Texas and, to a lesser degree, Louisiana and Tennessee. Any event that renders either Delek refinery temporarily or permanently unavailable could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to our unitholders. Due to our lack of diversification in assets and geographic location, an adverse development in our businesses or areas of operations, including adverse developments due to catastrophic events, weather, regulatory action and decreases in demand for crude oil and refined products, could have a significantly greater impact on our results of operations and cash available for distribution to our common unitholders than if we maintained more diverse assets and locations. Such events may constitute force majeure events under our commercial agreements, potentially resulting in the suspension, reduction or termination of multiple commercial agreements in the affected geographic area. In addition, during planned maintenance periods or a refinery turnaround, we expect that Delek, or its assignee, may only satisfy its minimum volume commitments with respect to our assets that serve such refinery. Please see “—Our contract counterparties may suspend, reduce or terminate their obligations under our various commercial agreements in certain circumstances, including events of force majeure, which could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to unitholders” and “—If Delek satisfies only its minimum obligations under, or if we are unable to renew or extend, the various commercial agreements we have with Delek, our ability to make distributions to our unitholders may be impaired.”

We are exposed to direct commodity price risk and interest rate risk, both of which may increase in the future. We may incur losses as a result of our forward contract activities and derivative transactions.

We typically own and hold a certain amount of inventory of light products in our business with respect to our wholesale marketing business in west Texas. Depending on our ability to sell such inventory, and the timing in which we do so, we could be exposed to risks related to the volatility of commodity prices in west Texas. Such volatility depends on many factors, including general market conditions and prices, demand for refined products in the west Texas market, the timing of refined product deliveries and downtime at refineries in the surrounding area. In addition, our actual product acquisitions from suppliers versus the amount we nominated to acquire may result in us being effectively long or short with respect to a given product and thus subject to further commodity price risk. This exposure to the volatility of commodity prices could have a material adverse effect on our business, financial condition, results of operations and ability to make quarterly cash distributions to our unitholders.


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To partially mitigate the risk of various financial exposures inherent in our business, including commodity price risk and interest rate risk, we selectively use derivative financial instruments, such as fuel-related derivative transactions, and may use interest rate swaps and interest rate cap agreements. In connection with such derivative transactions, we may be required to make payments to maintain margin accounts and to settle the contracts at their value in accordance with their terms and upon termination. The maintenance of required margin accounts, and the settlement of derivative contracts, could cause us to suffer losses or limit gains. In particular, derivative transactions could expose us to the risk of financial loss upon unexpected or unusual variations in the sales price of wholesale gasoline. We cannot assure you that the strategies underlying these transactions will be successful. If any of the instruments we utilize to manage our exposure to various types of risk is not effective, we may incur losses.

Our ability to expand may be limited if Delek’s business does not grow as expected.

Part of our growth strategy depends on the growth of Delek’s business. For example, in our terminals and storage business, we believe our growth will be driven in part by identifying and executing organic expansion or new construction projects that will result in increased or new throughput volumes from Delek, its assignees and third parties. Our organic growth opportunities will be limited if Delek is unable to acquire new assets for which our execution of organic projects is needed. Additionally, if Delek focuses on other growth areas that our business does not serve, or does not make capital expenditures to fund the organic growth of its operations, we may not be able to fully execute our growth strategy.

We may not be able to significantly increase or retain our third-party revenue due to competition and other factors, which could limit our ability to grow and may increase our dependence on Delek.

We can provide no assurance that we will be able to retain or attract third-party revenues, which could limit our ability to grow and increase our dependence on Delek. Our ability to increase our third-party revenue is subject to numerous factors beyond our control, including competition from third parties and the extent to which we have available capacity when third-party shippers require it. Further, under certain of our commercial agreements with Delek, we may not provide service to third parties with respect to certain assets without Delek’s consent, subject to limited exceptions. Furthermore, to the extent that we have capacity at our refined products terminals available for third-party volumes, competition from other existing or future refined products terminals owned by our competitors may limit our ability to utilize this available capacity.

The costs, scope, timelines and benefits of any construction projects we undertake may deviate significantly from our original plans and estimates.

One of our business strategies is to evaluate and make capital investments to expand our existing asset base through the development and construction of new or expanded logistics assets. At the same time, we also will need to devote significant resources to maintaining our asset base. However, in developing or maintaining such assets, we may experience unanticipated increases in the cost, scope and completion time for our construction or maintenance and repair projects. Equipment that we require to complete these projects may be unavailable to us at expected costs or within expected time periods. Additionally, labor expense may exceed our expectations. Due to these or other factors beyond our control, we may be unable to complete these projects within anticipated cost parameters and timelines. In addition, the benefits we realize from completed projects may take longer to realize and/or be less than we anticipated. Our inability to complete and/or realize the benefits of construction and/or maintenance projects in a cost-efficient and timely manner could have a material adverse effect on our business, financial condition, results of operations and our ability to make distributions.

If we are unable to obtain needed capital or financing on satisfactory terms to fund expansions of our asset base, our ability to make quarterly cash distributions may be diminished or our financial leverage could increase.

In order to expand our asset base, we will need to make expansion capital expenditures. If we do not make sufficient or effective expansion capital expenditures, we will be unable to expand our business operations and may be unable to maintain or raise the level of our quarterly cash distributions. We will be required to use cash from our operations or incur borrowings or sell additional limited partner units or interests in order to fund our expansion capital expenditures. Using cash from operations will reduce cash available for distribution to our common unitholders. Our ability to obtain financing or to access the capital markets for future equity or debt offerings may be limited by our financial condition at the time of any such financing or offering, as well as the covenants in our debt agreements, general economic conditions and contingencies and uncertainties that are beyond our control. Even if we are successful in obtaining funds for expansion capital expenditures through equity or debt financings, the terms thereof could limit our ability to pay distributions to our common unitholders. Moreover, incurring additional debt may significantly increase our interest expense and financial leverage, and issuing additional limited partner interests may result in significant common unitholder dilution and increase the aggregate amount of cash required to maintain the then-current distribution rate, which could materially decrease our ability to pay distributions at the then-current distribution rate.


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If third-party pipelines, terminals or other facilities interconnected to our pipeline systems or terminals become partially or fully unavailable, or if we are unable to fulfill our contractual obligations, our financial condition, results of operations, cash flows and ability to make distributions to our unitholders could be adversely affected.

Our pipelines and terminals connect to other pipelines, terminals and facilities owned and operated by unaffiliated third parties. Our shippers often need to use such pipelines, terminals and facilities; however, the continuing operation of such third-party pipelines, terminals and other facilities is not within our control.

These pipelines, terminals and other facilities may become unavailable because of testing, turnarounds, line repair, reduced operating pressure, lack of operating capacity, regulatory requirements, curtailments of receipt or deliveries due to insufficient capacity, corporate business decisions or because of damage from hurricanes or other operational hazards. In addition, we do not have interconnect agreements with all of these pipelines, terminals and other facilities, and the interconnect agreements we do have may be terminated in certain circumstances, including circumstances beyond our control, and on short notice. If any of these pipelines, terminals or other facilities becomes unable to receive or transport crude oil or refined products, we may be unable to perform our obligations under our commercial agreements with Delek and third parties, and our financial condition, results of operations, cash flows and ability to make distributions to our unitholders could be adversely affected.

Similarly, if additional shippers begin transporting volumes of refined products or crude oil over interconnecting pipelines, the allocations to us and other existing shippers on these interconnecting pipelines could be reduced, which could also reduce volumes distributed through our terminals or transported through our crude oil pipelines. Allocation reductions of this nature are not infrequent and are beyond our control. Any significant reduction in volumes could adversely affect our revenues and cash flow and our ability to make distributions to our unitholders.
 
An interruption or reduction of supply and delivery of refined products to our wholesale marketing business could result in a decline in our sales and profitability.

In our west Texas wholesale marketing business, we primarily sell refined products produced by refineries owned by unaffiliated third parties and Delek. We receive a majority of the products we sell in west Texas under one contract which runs through 2017 and has no renewal options. The remainder of the barrels sold in west Texas are spot purchased from various suppliers or refiners, including Delek. We could experience an interruption or reduction in the supply or delivery of refined products if our suppliers, or the refineries who supply us or our suppliers, partially or completely ceased operations, temporarily or permanently, or ceased to supply us with refined products for any reason. The ability of these refineries and our suppliers to supply refined products to us could be disrupted by anticipated events, such as scheduled upgrades or maintenance, as well as events beyond their control, such as unscheduled maintenance, fires, floods, storms, explosions, power outages, accidents, acts of terrorism or other catastrophic events, labor difficulties and work stoppages, governmental or private party litigation, or legislation or regulation that adversely impacts refinery operations. An interruption or reduction in the volume of refined products supplied to our wholesale business could adversely affect our sales and profitability.

We are exposed to the credit risks and certain other risks of our key customers and other contractual counterparties, including Delek and its assignees, and any material nonpayment or nonperformance by our key customers or other counterparties could adversely affect our business, financial condition, results of operations and our ability to make distributions to our unitholders.

We are subject to risks of loss resulting from nonpayment or nonperformance by our customers and other contractual counterparties. Any material nonpayment or nonperformance or default by our key customers or other contractual counterparties, including Delek or its assignees, could adversely affect our business, financial condition, results of operations and our ability to make distributions to our unitholders. Furthermore, some of our customers may be highly leveraged and subject to their own operating and regulatory risks. Any loss of our key customers, including Delek, could adversely affect our business, financial condition, results of operations and our ability to make distributions to our unitholders.

Restrictions in our revolving credit facility could adversely affect our business, financial condition, results of operations and ability to make quarterly cash distributions to our unitholders.

Our revolving credit facility limits our ability to, among other things:
 
incur or guarantee additional debt;
incur certain liens on assets;
dispose of assets;
make certain cash distributions or redeem or repurchase units;
change the nature of our business;
engage in certain mergers or acquisitions or make certain investments (including joint ventures); and

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enter into certain transactions with affiliates.

Our credit facility contains covenants requiring us to maintain certain financial ratios. Our ability to meet those financial ratios can be affected by events beyond our control, and we cannot assure you that we will meet those ratios. In addition, our credit facility contains events of default customary for agreements of this nature, including the occurrence of a change of control (which will occur if, among other things, (i) Delek ceases to own and control legally and beneficially at least 51% of the equity interests of our general partner, (ii) Delek Logistics GP, LLC ceases to be our sole general partner, or (iii) we fail to own and control legally and beneficially 100% of the equity interests of any other borrower under our credit facility, unless otherwise permitted thereunder).

The provisions of our credit facility may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our credit facility could result in a default or an event of default that could enable our lenders to declare the outstanding principal of that debt, together with accrued and unpaid interest and other outstanding amounts, to be immediately due and payable. Such event of default would also permit our lenders to foreclose on our assets serving as collateral for our obligations under the credit facility. If the payment of our debt is accelerated, our assets may be insufficient to repay such debt in full, and our unitholders could experience a partial or total loss of their investment. The credit facility also has cross-default provisions that will apply to any other material indebtedness we may have.

Our debt levels may limit our flexibility to obtain financing and to pursue other business opportunities.

As of December 31, 2016, we had approximately $392.6 million in debt outstanding. We have the ability to incur additional debt; however, such ability is subject to limitations under our revolving credit facility. Our level of debt could have important consequences to us, including the following:

our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on favorable terms;
our funds available for operations, future business opportunities and distributions to unitholders will be reduced by that portion of our cash flows required to make payments on our debt and any interest thereon;
we may be more vulnerable to competitive pressures or a downturn in our business or the economy generally; and
our flexibility in responding to changing business and economic conditions may be limited.

Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our current or future indebtedness, we will be forced to take actions such as reducing distributions, which is within our control, or such as reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity capital, which actions we may not be able to effect on satisfactory terms or at all.

Transportation on certain of our pipelines is subject to federal or state rate and service regulation, and the imposition and/or cost of compliance with such regulation could adversely affect our operations and cash flows available for distribution to our unitholders. In addition, certain of our other contracts are eligible for fee increases tied to other inflationary indexes, which could adversely affect our operations and cash flows available for distribution to our unitholders.

Certain of our pipelines provide services that may be subject to regulation by the FERC, under the ICA, the Energy Policy Act of 1992 and/or state regulators. The FERC uses prescribed rate methodologies for developing regulated tariff rates for interstate oil and product pipelines. The FERC's primary rate-making authority is currently price-indexing; if the methodology changes, the new methodology may result in tariffs that generate lower revenues and cash flows. The indexing method allows a pipeline to increase its rates based on a percentage change in the producer price index for finished goods and is not based on pipeline-specific costs. If the index falls, we will be required to reduce our rates that are based on the FERC's price indexing methodology if they exceed the new maximum available rate. In addition, changes in the index might not be large enough to fully reflect actual increases in our costs. The FERC's rate-making methodologies may limit our ability to set rates based on our true costs or may delay the use of rates that reflect increased costs. Any of the foregoing could adversely affect our revenues and cash flows. We note that the FERC index has been set at a level for the period from 2016-2021 that is lower than that which was in effect from 2010-2015; this is likely to result in lower annual rate increases for the coming 2017-2021 period for our transportation and other rates that are subject to the FERC index for annual adjustments, compared to the previous five-year period, and indeed the index level for the 2016 index rate adjustment required a decrease in certain of our interstate transportation rates to comply with the reduced ceiling level. Furthermore, on October 20, 2016, FERC issued an Advance Notice of Proposed Rulemaking regarding Revisions to Indexing Policies and Page 700 of FERC Form No. 6, (the “ANOPR”). If final rules are implemented as proposed in that ANOPR, our reporting burdens for providing to FERC annual throughput, revenue and cost of service information would likely increase. In addition, if implemented as proposed, FERC regulations based on the ANOPR would create new tests for whether our pipelines providing service subject to FERC tariffs could increase rates in accordance with the FERC index in a given year and could restrict our ability to increase our rates as a result.

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Shippers may protest, and the FERC may investigate, the lawfulness of new or changed tariff rates. The FERC can suspend those tariff rates for up to seven months. It can also require refunds of amounts collected, based on rates that are ultimately found to be unlawful, and prescribe new rates prospectively. The FERC and interested parties can also challenge tariff rates that have become final and effective.

The FERC can order new rates to take effect prospectively and order reparations for past rates that exceed the just and reasonable level for time periods up to two years prior to the date of a complaint. Due to the complexity of rate making, the lawfulness of any rate is never assured. A successful challenge of our rates could adversely affect our revenues. In addition, on December 15, 2016, FERC issued a Notice of Inquiry Regarding the Commission’s Policy for Recovery of Income Tax Costs, (the “NOI”). The NOI sought comments on how FERC should address any double recovery for partnership-owned pipelines resulting from FERC’s current income tax allowance and rate of return policies. If the NOI results in final regulations or policy changes that alter FERC’s current approach to liquids pipeline ratemaking and the relevant components of our interstate pipeline transportation rates, those changes could require us to change our rate design and potentially lower our rates if they are challenged on a cost of service basis. The FERC also regulates the terms and conditions of service, including access rights, for interstate transportation on common carrier pipelines subject to its jurisdiction.

While the FERC regulates rates and terms and conditions of service for transportation of crude oil or refined products in interstate commerce by pipeline, state agencies may regulate rates and terms and conditions of service for petroleum pipeline transportation in intrastate commerce. Whether a pipeline provides service in interstate commerce or intrastate commerce is highly fact-dependent and determined on a case-by-case basis. We cannot provide assurance that the FERC will not, at some point, assert that some or all of the transportation service we provide is within its jurisdiction. If the FERC were successful with any such assertion, its rate-making methodologies may limit our ability to set rates based on our actual costs, delay the use of rates that reflect increased costs and subject us to potentially burdensome and expensive operational, reporting and other requirements. Service on the East Texas Crude Logistics System is currently subject to a temporary waiver issued by FERC. If the conditions to the continued effectiveness of that East Texas Waiver Order are no longer true at any point, service on that system would become fully subject to FERC tariff filing requirements and other regulatory requirements for the provision of transportation service. If we file tariffs, we may be required to provide a cost justification for the transportation charge. We would also be required to provide service to all prospective shippers making reasonable requests for service without undue discrimination and to operate in a manner that does not provide any undue preference to shippers. The rates under such tariffs may be insufficient to allow us to recover fully our cost of providing service on the affected pipelines, which could adversely affect our business, financial condition and results of operations. In addition, regulation by the FERC may subject us to potentially burdensome and expensive operational, reporting and other requirements. We own pipeline assets in Texas, Arkansas and Louisiana. In Texas, a pipeline, with some exceptions, is required to operate as a common carrier and provide transportation without discrimination. Arkansas provides that all intrastate oil pipelines are common carriers, but it exercises light-handed regulation over petroleum pipelines. In Louisiana, all pipelines conveying petroleum from a point of origin within the state to a destination within the state are declared common carriers. The Louisiana Public Service Commission is empowered with the authority to establish reasonable rates and regulations for the transport of petroleum by a common carrier, mandating public tariffs and providing of transportation without discrimination. State commissions have generally not been aggressive in regulating common carrier pipelines, have generally not investigated the rates or practices of petroleum pipelines in the absence of shipper complaints and generally resolve complaints informally. If the regulatory commissions in the states in which we operate change their policies and aggressively regulate the rates or terms of service of pipelines operating in those states, it could adversely affect our business, financial condition and results of operations.

The Federal Trade Commission, the FERC and the CFTC hold statutory authority to monitor certain segments of the physical and futures energy commodities markets. These agencies have imposed broad regulations prohibiting fraud and manipulation of such markets. With regard to our physical sales of oil or other energy commodities, and any related hedging activities that we undertake, we are required to observe the market-related regulations enforced by these agencies, which hold substantial enforcement authority. Failure to comply with such regulations, as interpreted and enforced, could have a material adverse effect on our business, results of operations and financial condition.

In addition, the fees we charge on certain of our other contracts not involving regulated or other pipelines are also subject to change based on inflation based indices, such as certain sub-indices of the producer price index or the consumer price index. If the index rises, we will be able to increase our rates. However, if the index falls, we will be required to reduce our rates.

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Delek’s level of indebtedness, the terms of its borrowings and any potential future credit ratings could adversely affect our ability to grow our business, our ability to make cash distributions to our unitholders and our credit profile. Our ability to obtain credit in the future and our potential future credit rating may also be affected by Delek’s level of indebtedness and creditworthiness.

Delek must devote a substantial portion of its cash flows from operations to service its debt and lease obligations, thereby reducing the availability of its cash flows to fund its growth strategy, including capital expenditures, acquisitions and other business opportunities that would expand its needs for logistics operations. Furthermore, a higher level of indebtedness at Delek increases the risk that it may default on its obligations, including commercial agreements with us. The covenants contained in the agreements governing Delek’s outstanding and future indebtedness may limit its ability to borrow additional funds for development and make certain investments and may directly or indirectly impact our operations in a similar manner. For example, Delek’s indebtedness requires that any transactions it enters into with us must be on terms no less favorable to Delek than those that could have been obtained with an unrelated person. There is also the risk that if Delek were to default under certain of its debt obligations, Delek’s creditors would attempt to assert claims against our assets during the litigation of their claims against Delek. The defense of any such claims could be costly and could materially impact our financial condition, even absent any adverse determination. In the event these claims were successful, our ability to meet our obligations to our creditors, make distributions and finance our operations could be materially and adversely affected.

Although we are not contractually bound by and are not liable for Delek’s debt under its credit arrangements, we may be indirectly affected by certain prohibitions and limitations contained therein. Due to its ownership and control of our general partner, Delek has the ability to prevent us from taking actions that would cause Delek to violate any covenants in its credit arrangements, or otherwise to be in default under any of its credit arrangements. In deciding whether to prevent us from taking any such action, Delek will have no fiduciary duty to us or our unitholders. Delek’s compliance with the covenants in its credit arrangements may restrict our ability to undertake certain actions that might otherwise be considered beneficial, including borrowing under our credit facility.

Any debt instruments that Delek or any of its affiliates enter into in the future, including any amendments to existing credit facilities, may include additional or more restrictive limitations on Delek that may impact our ability to conduct our business. These additional restrictions could adversely affect our ability to finance our future operations or capital needs or engage in, expand or pursue our business activities.

None of our, or Delek’s, debt is presently rated by any credit rating agencies. If we were to seek a credit rating in the future, our credit rating may be adversely affected by the leverage or any future credit rating of Delek, as credit rating agencies may consider the leverage and credit profile of Delek and its affiliates, because of their ownership interest in and control of us and because Delek accounts for a substantial majority of our contribution margin. Any adverse effect on our potential credit rating could increase our cost of borrowing or hinder our ability to raise financing in the capital markets, which could impair our ability to grow our business and make cash distributions to our unitholders.

Increases in interest rates could adversely impact the price of our common units, our ability to issue equity or incur debt for acquisitions or other purposes and our ability to make cash distributions at our intended levels.

Floating interest rates on our existing credit facility, to the extent not hedged, and interest rates on future credit facilities and debt offerings, could be higher than current levels, causing our financing costs to increase accordingly. As with other yield-oriented securities, our unit price is impacted by the level of our cash distributions and implied distribution yield. The distribution yield is often used by investors to compare and rank yield-oriented securities for investment decision-making purposes. Therefore, changes in interest rates, either positive or negative, may affect the yield requirements of investors who invest in our common units, and a rising interest rate environment could have an adverse impact on the price of our common units, our ability to issue equity or incur debt for acquisitions or other purposes and our ability to make cash distributions at our intended levels.

Our right of first offer to acquire certain of Delek’s existing logistics assets and certain assets that it may acquire or construct in the future is subject to risks and uncertainty, and ultimately we may not acquire any of those assets.

The Omnibus Agreement provides us with a right of first offer on certain of Delek’s existing logistics assets and certain assets that it may acquire or construct in the future, subject to certain exceptions and time limitations. The consummation and timing of any future acquisitions pursuant to this right will depend on, among other things, Delek’s willingness to offer such assets for sale and obtain any necessary consents, our ability to negotiate acceptable purchase agreements and commercial agreements with respect to such assets and our ability to obtain financing on acceptable terms. We can offer no assurance that we will be able to successfully consummate any future acquisitions pursuant to our right of first offer, and Delek is under no obligation to accept any offer that we may choose to make. In addition, we may decide not to exercise our right of first offer, if and when any assets are offered for sale, and our decision will not be subject to unitholder approval. In addition, our right of first offer may be terminated by Delek at any time in the event that it no longer controls our general partner.


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If we are unable to make investments in joint ventures or acquisitions on economically acceptable terms from Delek or third parties, our future growth could be limited, and any investments or acquisitions we may make may reduce, rather than increase, our cash flows and ability to make distributions to unitholders.

A portion of our strategy to grow our business and increase distributions to unitholders is dependent on our ability to make acquisitions or invest in joint ventures that result in an increase in cash flow. If we are unable to make acquisitions from Delek or third parties or invest in joint ventures, because we are unable to identify attractive acquisition or project candidates or negotiate acceptable purchase contracts, we are unable to obtain financing for these acquisitions or investments on economically acceptable terms, we are outbid by competitors or we or the seller are unable to obtain any necessary consents, our future growth and ability to increase distributions to unitholders may be limited. Furthermore, even if we do consummate acquisitions or investments in joint ventures that we believe will be accretive, they may in fact result in a decrease in cash flow. Any acquisition or investment involves potential risks, including, among other things:

mistaken assumptions about revenues and costs, including synergies;
the assumption of known or unknown liabilities;
limitations on rights to indemnity from the seller;
mistaken assumptions about the overall costs of equity or debt;
the diversion of management’s attention from other business concerns;
ineffective or poor integration of such acquisitions;
unforeseen difficulties operating multi-customer and product assets in new product areas or new markets; and
customer or key employee losses at the acquired businesses.

If we consummate any future acquisitions or investments in joint ventures, our capitalization and results of operations may change significantly, and unitholders will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of these funds and other resources.

We may be unsuccessful in integrating the operations of the assets we have acquired or of any future acquisitions with our existing operations and in realizing all or any part of the anticipated benefits of any such acquisitions.

From time to time, we evaluate and acquire assets and businesses that we believe complement our existing assets and businesses. Acquisitions may require substantial capital or the incurrence of substantial indebtedness. Our capitalization and results of operations may change significantly as a result of future acquisitions. Acquisitions and business expansions involve numerous risks, including difficulties in the assimilation of the assets and operations of the acquired businesses, inefficiencies and difficulties that arise because of improper assumptions regarding the new assets, unfamiliarity with new assets and the businesses associated with them and new geographic areas and the diversion of management’s attention from other business concerns. Further, unexpected costs and challenges may arise whenever businesses with different operations or management are combined, and we may experience unanticipated delays in realizing the benefits of an acquisition, if at all. Also, following an acquisition, we may discover previously unknown liabilities associated with the acquired business or assets for which we have no recourse under applicable indemnification provisions.

The expansion of existing assets and construction of new assets, including through joint venture investments, may not result in revenue increases and will be subject to regulatory, environmental, political, legal, economic and other risks, which could adversely affect our results of operations and financial condition.

A portion of our strategy to grow and increase distributions to unitholders is dependent on our ability to expand existing assets and to construct additional assets, including through investments in joint ventures. The construction of a new pipeline or terminal, or the expansion of an existing pipeline or terminal, involves numerous regulatory, environmental, political and legal uncertainties, most of which are beyond our control. If we, or joint ventures we invest in, undertake these types of projects, they may not be completed on schedule, or at all, or at the budgeted cost. Moreover, we, or the joint ventures we invest in, may not receive sufficient long-term contractual commitments from customers to provide the revenue needed to support such projects. Even if such commitments are received, an increase in revenue may not be realized for an extended period of time. For instance, if we build, or invest in a joint venture that builds, a new pipeline, the construction will occur over an extended period of time, and we will not receive any material increases in revenues until after completion of the project, if at all. In addition, we, or the joint ventures we invest in, may construct facilities to capture anticipated future growth in production in a region or gain access to crude supplies at lower costs, and such growth or access may not materialize. As a result, new facilities may not be able to attract enough throughput to achieve the expected return on investment, which could adversely affect our results of operations and financial condition and our ability to make distributions to our unitholders.





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We do not own all of the land on which most of our pipelines and several of our facilities are located, which could result in disruptions to our operations.

We do not own all of the land on which most of our pipelines, tank farms and terminal facilities are located, and we are therefore subject to the possibility of more onerous terms and/or increased costs to retain necessary land use if we do not have valid rights-of-way or leases, if such rights-of-way or leases lapse or terminate or if our facilities are not properly located within the boundaries of such leases or rights-of-way. We obtain the rights to construct and operate our pipelines on land owned by third parties and governmental agencies, and some of those agreements may grant us those rights for only a specific period of time. Our loss of such rights, through our inability to renew any rights-of-way contracts, or a significant increase in the costs of these rights, could have a material adverse effect on our business, financial condition, results of operations and cash flows and our ability to make distributions to our unitholders.

We could incur substantial costs or disruptions in our business if we cannot obtain or maintain necessary permits and authorizations or otherwise comply with health, safety, environmental and other laws and regulations.

Our operations require numerous permits and authorizations under various laws and regulations. These authorizations and permits are subject to revocation, renewal or modification and can require operational changes to limit impacts or potential impacts on the environment and/or health and safety. A violation of authorization or permit conditions or other legal or regulatory requirements could result in substantial fines, criminal sanctions, permit revocations, injunctions and/or facility shutdowns. In addition, material modifications of our operations could require modifications to our existing permits or upgrades to our existing pollution control equipment. Any or all of these matters could have a negative effect on our business, results of operations and cash flows.

Climate change legislation or regulations restricting emissions of greenhouse gases could result in increased operating and capital costs and reduced demand for our products and services.

In December 2009, the EPA published its findings that emissions of greenhouse gases, or GHGs, present a danger to public health and the environment because emissions of such gases are, according to the EPA, contributing to the warming of the Earth’s atmosphere and other climatic conditions. Based on these findings, the EPA adopted two sets of regulations that restrict emissions of GHGs under existing provisions of the federal Clean Air Act, including one that requires a reduction in emissions of GHGs from motor vehicles and another that regulates GHG emissions from certain large stationary sources under the Clean Air Act Prevention of Significant Deterioration (“PSD”) and Title V permitting programs. In addition, the EPA expanded its existing GHG emissions reporting rule to include onshore oil and natural gas processing, transmission, storage, and distribution activities, beginning in 2012 for emissions occurring in 2011. On October 23, 2015, the EPA published as a final rule the Clean Power Plan, which sets performance rates for GHG emissions from power generating units firing coal, oil or natural gas. While we do not operate power plants governed by this final rule, the impact of the rule on demand for oil, coal, natural gas and renewable energy sources, including crude oil and refined products transported and stored by us remains unclear. On February 9, 2016, the U.S. Supreme Court stayed the Clean Power Plan final rule until pending legal challenges are resolved; however, with the change in administration, the Clean Power Plan rule is not currently expected to be implemented. Congress has also from time to time considered legislation to reduce emissions of GHGs. Efforts have been made,and continue to be made, in the international community toward the adoption of international treaties or protocols that would address global climate change issues. Most recently, in April 2016, the United States became a signatory to the 2015 United Nations Conference on Climate Change, which led to the creation of the Paris Agreement. The Paris Agreement, which became effective by its terms on November 4, 2016, will require countries to review and "represent a progression" in their intended nationally determined contributions, which set GHG emission reduction goals, every five years, beginning in 2020. Although it is not possible to predict the requirements of any GHG legislation or regulations that may be enacted or promulgated, any laws or regulations that may be adopted to restrict or reduce GHG emissions may require us to incur increased operating costs. If we are unable to maintain sales of our refined products at a price that reflects such increased costs, there could be a material adverse effect on our business, financial condition and results of operations. Further, any increase in the prices of refined products resulting from such increased costs could have a material adverse effect on our business, financial condition or results of operations. Moreover, GHG regulation could also impact the consumption of refined products, thereby affecting the demand for our services.

In 2010, the EPA and the National Highway Transportation Safety Administration (NHTSA) finalized new standards, raising the required Corporate Average Fuel Economy, or CAFE, standard of the nation’s passenger fleet by 40% to approximately 35 miles per gallon by 2016 and imposing the first ever federal GHG emissions standards on cars and light trucks. In September 2011, the EPA and the DOT finalized first-time standards for fuel economy of medium and heavy duty trucks. On August 28, 2012, the EPA and NHTSA announced final regulations that mandated further decreases in passenger vehicle GHG emissions and increases in fuel economy beginning with 2017 model year vehicles and increasing to the equivalent of 54.5 miles per gallon by 2025. During 2016, the EPA conducted a mid-term evaluation of progress in meeting vehicle GHG standards and in January 2017 the EPA issued a determination to maintain the current GHG emissions standards for model year (MY) 2022-2025 vehicles. In August 2016, the EPA and the U.S. Department of Transportation's National Highway Traffic Safety Administration (NHTSA) jointly finalized standards for medium- and heavy-duty vehicles regulating fuel efficiency and carbon pollution. Such increases in fuel economy standards and potential electrification of the vehicle fleet, along with mandated increases in use

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of renewable fuels discussed above, could result in decreasing demand for petroleum fuels. Decreasing demand for petroleum fuels could materially affect profitability at Delek’s refineries, which could adversely impact our business, results of operations and cash flows.

Our operations are subject to federal and state laws and regulations relating to product quality specifications, and we could be subject to damages based on claims brought against us by our customers or lose customers as a result of the failure of products we distribute to meet certain quality specifications.

Various federal and state agencies prescribe specific product quality specifications for refined products, including vapor pressure, sulfur content, ethanol content and biodiesel content. Changes in product quality specifications or blending requirements could reduce our throughput volume, require us to incur additional handling costs or require capital expenditures. For example, mandated increases in use of renewable fuels could require the construction of additional storage and blending equipment. If we are unable to recover these costs through increased revenues, our cash flows and ability to pay cash distributions to our unitholders could be adversely affected. Violations of product quality laws attributable to our operations could subject us to significant fines and penalties as well as negative publicity. In addition, changes in the product quality of the products we receive on our pipeline system could reduce or eliminate our ability to blend products.

A terrorist attack on our assets, or threats of war or actual war, may hinder or prevent us from conducting our business.
 
Terrorist attacks in the United States, as well as events occurring in response or similar to or in connection with such attacks, including political instability in various Middle Eastern countries, may harm our business. Energy-related assets (which could include pipelines and terminals such as ours) may be at greater risk of future terrorist attacks than other possible targets in the United States. In addition, the State of Israel, where Delek Group, the former parent company of Delek, is based, has suffered armed conflicts and political instability in recent years. We may be more susceptible to terrorist attack as a result of our connection to Israel. In the future, certain of the directors of our general partner may reside in Israel.

A direct attack on our assets, Delek’s assets or the assets of others used by us could have a material adverse effect on our business, financial condition and results of operations. In addition, any terrorist attack or continued political instability in the Middle East could have an adverse impact on energy prices, including prices for the crude oil and other feedstocks we transport and refined petroleum products, and an adverse impact on the margins from our operations. Disruption or significant increases in energy prices could also result in government-imposed price controls.

Further, changes in the insurance markets attributable to terrorist attacks could make certain types of insurance more difficult for us to obtain. Moreover, the insurance that may be available to us may be significantly more expensive than our existing insurance coverage. Instability in the financial markets as a result of terrorism or war could also affect our ability to raise capital, including our ability to repay or refinance debt.
 
Our customers’ operating results are seasonal and generally lower in the first and fourth quarters of the year. Our customers depend on favorable weather conditions in the spring and summer months.

The volume and throughput of crude oil 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 of such products in the markets served directly or indirectly by our assets. Supply and demand for such products fluctuate 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, while demand for asphalt products, which is a substantial product of Delek's El Dorado Refinery, is lower in the winter months. In addition, our refining customers, such as Delek, occasionally slow or shut down operations to perform planned maintenance during the winter, when demand for their products is lower. Accordingly, these factors can affect the need for crude oil or finished products by our customers, and therefore limit our volumes or throughput during these periods, and could adversely affect our customers’ business, financial condition and results of operations, which may adversely affect our business, financial condition and results of operations.

Regulations adopted by the Commodity Futures Trading Commission could have an adverse effect on our ability to use derivative instruments to reduce the effect of commodity price, interest rate and other risks associated with our business.

The U.S. Congress has adopted the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”), which is comprehensive financial reform legislation that, among other things, establishes new federal oversight and regulation of over-the-counter derivatives and many of the entities that participate in that market. The Dodd-Frank Act was enacted in 2010, and the Commodity Futures Trading Commission (“CFTC”), and the SEC, along with certain other regulators, have promulgated final rules to implement many of the Dodd-Frank Act’s provisions relating to over-the-counter derivatives. Most of these rules have been finalized, while others have not; as a result, the final form and timing of the implementation of certain parts of the regulatory regime affecting commodity derivatives remains uncertain. Among other consequences of the new regulations, entities that enter into derivatives (including futures and exchange-traded

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and over-the-counter swaps) are expected to be subject to aggregate position limits for certain futures, options and swaps (under a pending regulatory proposal that is not yet final), and are currently subject to recordkeeping and reporting requirements. There can be no assurance that, when fully implemented, this regulatory regime will not have a material adverse effect on our ability to hedge our exposure to commodity prices, interest rates and other risks to the extent that we use derivatives to do so.

We rely on information technology in our operations, and any material failure, inadequacy, interruption or security failure of that technology could harm our business.

We are heavily dependent on technology infrastructure and rely upon certain critical information systems for the effective operation of our business. These information systems include data network and telecommunications, internet access and our websites, and various computer hardware equipment and software applications, including those that are critical to the safe operation of our pipelines and terminals. These information systems are subject to damage or interruption from a number of potential sources, including natural disasters, software viruses or other malware, power failures, cyber attacks and other events to the extent that these information systems are under our or Delek’s control. Delek has implemented measures, such as virus protection software, intrusion detection systems and emergency recovery processes to address the outlined risks. However, security measures for information systems cannot be guaranteed to be failsafe. Any compromise of our data security, or our inability to use or access these information systems at critical points in time, could unfavorably impact the timely and efficient operation of our business and subject us to additional costs and liabilities, which could adversely affect our results of operations. Finally, federal legislation relating to cyber-security threats could impose additional requirements on our operations.


Risks Relating to Our Partnership Structure

Our general partner and its affiliates, including Delek and the Individual GP Owners, have conflicts of interest with us and limited duties to us and our unitholders, and they may favor their own interests to the detriment of us and our other common unitholders.

Delek controls our general partner and appoints all of the officers and directors of our general partner. In addition, three members of the board of directors of our general partner, each of whom also serve as executive officers of Delek, own a small percentage of our general partner (the "Individual GP Owners"). See "Item 10 - Directors, Executive Officers and Corporate Governance." All of the officers and three of the directors of our general partner (who are also the three Individual GP Owners) are also officers and/or directors of Delek. Although our general partner has a contractual obligation to manage us in a manner that is beneficial to us and our unitholders, the directors and officers of our general partner have a fiduciary duty to manage our general partner in a manner that is beneficial to Delek. Conflicts of interest will arise from time to time between Delek, the Individual GP Owners, and our general partner, on the one hand, and us and our unitholders, on the other hand. In resolving these conflicts of interest, our general partner may favor its own interests and the interests of Delek and the Individual GP Owners over our interests and the interests of our unitholders. These conflicts include the following situations, among others:

Our Partnership Agreement replaces the fiduciary duties that would otherwise be owed by our general partner with contractual standards governing its duties, limits our general partner’s liabilities and restricts the remedies available to our unitholders for actions that, without such limitations, might constitute breaches of fiduciary duty.
Neither our Partnership Agreement nor any other agreement requires Delek to pursue a business strategy that favors us or utilizes our assets, including whether to increase or decrease refinery production, whether to shut down or reconfigure a refinery or what markets to pursue or grow. The directors and officers of Delek have a fiduciary duty to make these decisions in the best interests of the stockholders of Delek, which may be contrary to our interests. Delek may choose to shift the focus of its investment and growth to areas not served by our assets.
Delek, as our primary customer, has an economic incentive to cause us not to seek higher service fees, even if such higher fees could be obtained in arm’s-length, third-party transactions. Furthermore, under many of our commercial agreements with them, Delek’s consent is required before we may enter into an agreement with any third party with respect to certain of our assets, including those that serve the El Dorado and Tyler Refineries, and Delek has an incentive to cause us not to pursue such third-party contracts in certain circumstances.
Our general partner is allowed to take into account the interests of parties other than us, such as Delek, in resolving conflicts of interest.
All of the officers and three of the directors of our general partner (who are also the three Individual GP Owners) are also officers and/or directors of Delek and owe fiduciary duties to Delek. These officers will also devote significant time to the business of Delek and will be compensated by Delek accordingly.
Delek may be constrained by the terms of its debt instruments from taking actions, or refraining from taking actions, that may be in our best interests.
Except in limited circumstances, our general partner has the power and authority to conduct our business without unitholder approval.
Disputes may arise under our commercial agreements with Delek.

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Our general partner determines the amount and timing of asset purchases and sales, borrowings, issuances of additional partnership units and the creation, reduction or increase of cash reserves, each of which can affect the amount of cash available for distribution to our unitholders.
Our general partner determines the amount and timing of any capital expenditures and whether a capital expenditure is classified as a maintenance capital expenditure, which reduces operating surplus, or an expansion or investment capital expenditure, which does not reduce operating surplus. This determination can affect the amount of cash that is distributed to our unitholders.
Our general partner determines which costs incurred by it are reimbursable by us.
Our general partner may cause us to borrow funds in order to permit the payment of cash distributions, even if the purpose or effect of the borrowing is to make a distribution on their common units or to make incentive distributions.
Our Partnership Agreement permits us to classify up to $25.0 million as operating surplus, even if it is generated from asset sales, non-working capital borrowings or other sources that would otherwise constitute capital surplus. This cash may be used to fund distributions on our general partner units or to our general partner in respect of the incentive distribution rights.
Our Partnership Agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered to us or entering into additional contractual arrangements with any of these entities on our behalf.
Our general partner intends to limit its liability regarding our contractual and other obligations.
Our general partner may exercise its right to call and purchase all of the common units not owned by it and its affiliates if they own more than 80% of the common units.
Our general partner controls the enforcement of the obligations that it and its affiliates owe to us, including Delek’s obligations under the Omnibus Agreement and its commercial agreements with us.
Our general partner decides whether to retain separate counsel, accountants or other advisers to perform services for us.
Our general partner may transfer its incentive distribution rights without unitholder approval.
Our general partner may elect to cause us to issue common units to it in connection with a resetting of the target distribution levels related to our incentive distribution rights without the approval of the conflicts committee of the board of directors of our general partner or our unitholders. This election may result in lower distributions to our common unitholders in certain situations.

Our Partnership Agreement replaces the fiduciary duties that would otherwise be owed by our general partner with contractual standards governing its duties.

Our Partnership Agreement contains provisions that eliminate the fiduciary standards to which our general partner would otherwise be held by state fiduciary duty law and replaces those duties with several different contractual standards. For example, our Partnership Agreement permits our general partner to make a number of decisions in its individual capacity, as opposed to in its capacity as our general partner, free of any duties to us and our unitholders other than the implied contractual covenant of good faith and fair dealing, which means that a court will enforce the reasonable expectations of the partners where the language in the Partnership Agreement does not provide for a clear course of action. This provision entitles our general partner to consider only the interests and factors that it desires and relieves it of any duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or our limited partners. Examples of decisions that our general partner may make in its individual capacity include:

how to allocate corporate opportunities among us and its other affiliates;
whether to exercise its limited call right;
whether to seek approval of the resolution of a conflict of interest by the conflicts committee of the board of directors of our general partner;
how to exercise its voting rights with respect to the units it owns;
whether to exercise its registration rights;
whether to elect to reset target distribution levels;
whether to transfer the incentive distribution rights to a third party; and
whether or not to consent to any merger or consolidation of the Partnership or amendment to the Partnership Agreement.

Delek may compete with us.

Delek may compete with us. Under the Omnibus Agreement, Delek and its affiliates have agreed not to engage in, whether by acquisition or otherwise, the business of owning or operating crude oil or refined products pipelines, terminals or storage facilities in the United States that are not within, directly connected to, substantially dedicated to, or otherwise an integral part of, any refinery owned, acquired or constructed by Delek. This restriction, however, does not apply to:

any assets that were owned by Delek upon the completion of the Offering (including replacements or expansions of those assets);
any asset or business that Delek acquires or constructs that has a fair market value of less than $5.0 million; and

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any asset or business that Delek acquires or constructs that has a fair market value of $5.0 million or more if we have been offered the opportunity to purchase the asset or business for fair market value not later than six months after completion of such acquisition or construction, and we decline to do so.

As a result, Delek has the ability to construct assets which directly compete with our assets. The limitations on the ability of Delek to compete with us are terminable by either party if Delek ceases to control our general partner.
 
Pursuant to the terms of our Partnership Agreement, the doctrine of corporate opportunity, or any analogous doctrine, does not apply to our general partner or any of its affiliates, including its executive officers and directors and Delek. Any such person or entity that becomes aware of a potential transaction, agreement, arrangement or other matter that may be an opportunity for us will not have any duty to communicate or offer such opportunity to us. Any such person or entity will not be liable to us or to any limited partner for breach of any fiduciary duty or other duty by reason of the fact that such person or entity pursues or acquires such opportunity for itself, directs such opportunity to another person or entity or does not communicate such opportunity or information to us. This may create actual and potential conflicts of interest between us and affiliates of our general partner and result in less than favorable treatment of us and our common unitholders.

If unitholders are not eligible holders, their common limited partner units may be subject to redemption.

We have adopted certain requirements regarding those investors who may own our common units. Eligible holders are limited partners whose (i) federal income tax status is not reasonably likely to have a material adverse effect on the rates that can be charged by us on assets that provide services that are subject to regulation by the FERC or an analogous regulatory body and (ii) nationality, citizenship or other related status would not create a substantial risk of cancellation or forfeiture of any property in which we have an interest, in each case as determined by our general partner with the advice of counsel. If you are not an eligible holder, in certain circumstances as set forth in our Partnership Agreement, your units may be redeemed by us at the then-current market price. The redemption price will be paid in cash or by delivery of a promissory note, as determined by our general partner.
 
Our Partnership Agreement requires that we distribute all of our available cash, which could limit our ability to grow and make acquisitions.

We expect that we will distribute all of our available cash quarterly to our unitholders and, to the extent not otherwise reserved for, will rely primarily upon cash flows from operations, borrowings under the Amended and Restated Credit Agreement and potential future issuances of debt and equity securities, to fund our acquisitions and expansion capital expenditures. As a result, to the extent we are unable to finance growth externally, our cash distribution policy could significantly impair our ability to grow.

In addition, because we intend to distribute all of our available cash, our growth may not be as fast as that of businesses that reinvest their available cash to expand ongoing operations. To the extent we issue additional units in connection with any acquisitions or expansion capital expenditures, the payment of distributions on those additional units may increase the risk that we will be unable to maintain or increase our per-unit distribution level. There are no limitations in our Partnership Agreement, and we do not anticipate there being limitations in any of our credit facilities, on our ability to issue additional units, including units ranking senior to the common limited partner units. The incurrence of additional borrowings, or other debt, to finance our growth strategy would result in increased interest expense, which in turn may impact the available cash that we have to distribute to our unitholders.
 
Our Partnership Agreement restricts the remedies available to holders of our common limited partner units for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.

Our Partnership Agreement contains provisions that restrict the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty under state fiduciary duty law. For example, our Partnership Agreement provides that:

whenever our general partner, the board of directors of our general partner or any committee thereof (including the conflicts committee) makes a determination or takes, or declines to take, any other action in their respective capacities, our general partner, the board of directors of our general partner and any committee thereof (including the conflicts committee), as applicable, is required to make such determination, or take or decline to take such other action, in good faith, meaning that it subjectively believed that the decision was in the best interests of the Partnership, and, except as specifically provided by our Partnership Agreement, will not be subject to any other or different standard imposed by our Partnership Agreement, Delaware law, or any other law, rule or regulation, or at equity;
our general partner will not have any liability to us or our unitholders for decisions made in its capacity as a general partner so long as such decisions are made in good faith;

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our general partner and its officers and directors will not be liable for monetary damages to us or our limited partners resulting from any act or omission, unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that our general partner or its officers and directors, as the case may be, acted in bad faith or engaged in fraud or willful misconduct or, in the case of a criminal matter, acted with knowledge that the conduct was criminal; and
our general partner will not be in breach of its obligations under the Partnership Agreement (including any duties to us or our unitholders) if a transaction with an affiliate or the resolution of a conflict of interest is:
approved by the conflicts committee of the board of directors of our general partner, although our general partner is not obligated to seek such approval;
approved by the vote of a majority of the outstanding common limited partner units, excluding any common units owned by our general partner and its affiliates;
determined by the board of directors of our general partner to be on terms no less favorable to us than those generally being provided to or available from unrelated third parties; or
determined by the board of directors of our general partner to be fair and reasonable to us, taking into account the totality of the relationships among the parties involved, including other transactions that may be particularly favorable or advantageous to us.

In connection with a situation involving a transaction with an affiliate or a conflict of interest, any determination by our general partner or its conflicts committee must be made in good faith. If an affiliate transaction or the resolution of a conflict of interest is not approved by our common unitholders or the conflicts committee and the board of directors of our general partner determines that the resolution or course of action taken with respect to the affiliate transaction or conflict of interest satisfies either of the standards set forth in the third and fourth sub bullets above, then it will be presumed that, in making its decision, the board of directors of our general partner acted in good faith, and in any proceeding brought by or on behalf of any limited partner or the Partnership challenging such determination, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption. The general partner may still take action with respect to any affiliate transactions or the resolution of a conflict of interest without satisfying any of the sub bullets above. In such case, it is not entitled to the presumption of good faith discussed above.

The administrative services fee and reimbursements due to our general partner and its affiliates for services provided to us or on our behalf will reduce our cash available for distribution to our common unitholders. The amount and timing of such reimbursements will be determined by our general partner.

Prior to making any distribution on our common limited partner units, we will reimburse our general partner and its affiliates, including Delek, for costs and expenses they incur and payments they make on our behalf. Under the Omnibus Agreement, we will pay Delek an annual fee and reimburse Delek and its subsidiaries for Delek’s provision of various centralized corporate services. Additionally, we will reimburse Delek for direct or allocated costs and expenses incurred on our behalf, including administrative costs, such as compensation expense for those persons who provide services necessary to run our business, and insurance expenses. We also expect to incur incremental annual general and administrative expense as a result of being a publicly traded partnership. Our Partnership Agreement provides that our general partner will determine in good faith the expenses that are allocable to us. The reimbursement of expenses and payment of fees, if any, to our general partner and its affiliates will reduce the amount of available cash to pay cash distributions to our common unitholders.

Holders of our common limited partner units have limited voting rights and are not entitled to elect our general partner or its directors.

Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders will have no right on an annual or ongoing basis to elect our general partner or its board of directors. Rather, the board of directors of our general partner will be appointed by the members of the general partner, which currently consist of Delek and Messrs. Yemin, Ginzburg and Green. Furthermore, if the unitholders are dissatisfied with the performance of our general partner, they will have little ability to remove our general partner. As a result of these limitations, the price at which the common limited partner units will trade could be diminished because of the absence or reduction of a takeover premium in the trading price. Our Partnership Agreement also contains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions limiting the unitholders’ ability to influence the manner or direction of management.

Even if holders of our common limited partner units are dissatisfied, they cannot remove our general partner without its consent.

Unitholders are unable to remove our general partner without its consent, because our general partner and its affiliates, including Delek, own sufficient units to be able to prevent its removal. The vote of the holders of at least 66 2/3% of all outstanding common limited partner units is required to remove our general partner. As of February 17, 2017, Delek owned 62.0% of our outstanding common limited partner units.

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Our Partnership Agreement restricts the voting rights of unitholders owning 20% or more of our common limited partner units.
 
Unitholders’ voting rights are further restricted by a provision of our Partnership Agreement providing that any units held by a person that owns 20% or more of any class of units then outstanding, other than our general partner, its affiliates, their transferees and persons who acquired such units with the prior approval of the board of directors of our general partner, cannot vote on any matter.

Our general partner’s interest in us and the control of our general partner may be transferred to a third party without unitholder consent.

Our Partnership Agreement does not restrict the ability of Delek to transfer all or a portion of its general partner interest or its ownership interest in our general partner to a third party. Our general partner, or the new owner of our general partner, would then be in a position to replace the board of directors and officers of our general partner with its own designees and thereby exert significant control over the decisions made by the board of directors and officers of our general partner.
 
The incentive distribution rights of our general partner may be transferred to a third party without unitholder consent.
 
Our general partner may transfer its incentive distribution rights to a third party at any time without the consent of our unitholders. If our general partner transfers its incentive distribution rights to a third party but retains its general partner interest, our general partner may not have the same incentive to grow our partnership and increase quarterly distributions to unitholders over time as it would if it had retained ownership of its incentive distribution rights. For example, a transfer of incentive distribution rights by our general partner could reduce the likelihood of Delek selling or contributing additional assets to us, as Delek would have less of an economic incentive to grow our business, which in turn would impact our ability to grow our asset base.

We may issue additional units without unitholder approval, which would dilute unitholder interests.

Our Partnership Agreement does not limit the number of additional limited partner interests, including limited partner interests that rank senior to the common limited partner units, that we may issue at any time without the approval of our unitholders. The issuance by us of additional common limited partner units or other equity securities of equal or senior rank will have the following effects:

our existing unitholders’ proportionate ownership interest in us will decrease;
the amount of cash available for distribution on each unit may decrease;
because the amount payable to holders of incentive distribution rights is based on a percentage of the total cash available for distribution, the distributions to holders of incentive distribution rights will increase even if the per-unit distribution on common limited partner units remains the same;
the ratio of taxable income to distributions may increase;
the relative voting strength of each previously outstanding unit may be diminished; and
the market price of the common limited partner units may decline.

Delek may sell units in the public or private markets, and such sales could have an adverse impact on the trading price of the common units.

Delek holds 15,077,092 common limited partner units. In addition, we have agreed to provide Delek with certain registration rights. The sale of these units in the public or private markets could have an adverse impact on the price of the common units or on any trading market that may develop.

Our general partner intends to limit its liability regarding our obligations.

Our general partner intends to limit its liability under contractual arrangements, so that the counterparties to such arrangements have recourse only against our assets and not against our general partner or its assets. Our general partner may therefore cause us to incur indebtedness or other obligations that are nonrecourse to our general partner. Our Partnership Agreement permits our general partner to limit its liability, even if we could have obtained more favorable terms without the limitation on liability. In addition, we are obligated to reimburse or indemnify our general partner to the extent that it incurs obligations on our behalf. Any such reimbursement or indemnification payments would reduce the amount of cash otherwise available for distribution to our unitholders.

Our general partner has a limited call right that may require our unitholders to sell their units at an undesirable time or price.
 
If at any time our general partner and its affiliates own more than 80% of our common units, our general partner will have the right, which it may assign to any of its affiliates or to us, but not the obligation, to acquire all, but not less than all, of the common units held by

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unaffiliated persons at a price that is not less than their then-current market price, as calculated pursuant to the terms of our Partnership Agreement. As a result, our unitholders may be required to sell their common units at an undesirable time or price and may not receive any positive return on their investment. Our unitholders may also incur a tax liability upon any such sale of their units to Delek. At February 17, 2017, Delek owned 15,077,092 common limited partner units, or 62.0% of our total outstanding common limited partner units.

Our general partner, or any transferee holding a majority of the incentive distribution rights, may elect to cause us to issue common limited partner units to it in connection with a resetting of the minimum quarterly distribution and the target distribution levels related to the incentive distribution rights, without the approval of the conflicts committee of our general partner or our unitholders. This election may result in lower distributions to our common unitholders in certain situations.

The holder or holders of a majority of the incentive distribution rights, which is currently our general partner, have the right, at any time when there are no subordinated units outstanding and such holders have received incentive distributions at the highest level to which they are entitled (48.0%) for each of the prior four consecutive fiscal quarters (and the amount of each such distribution did not exceed adjusted operating surplus for each such quarter), to reset the minimum quarterly distribution and the initial target distribution levels at higher levels based on our cash distribution at the time of the exercise of the reset election. Following a reset election, the minimum quarterly distribution will be reset to an amount equal to the average cash distribution per unit for the two fiscal quarters immediately preceding the reset election (such amount is referred to as the “reset minimum quarterly distribution”), and the target distribution levels will be reset to correspondingly higher levels based on percentage increases above the reset minimum quarterly distribution. Our general partner has the right to transfer the incentive distribution rights at any time, in whole or in part, and any transferee holding a majority of the incentive distribution rights shall have the same rights as our general partner with respect to resetting target distributions.

In the event of a reset of the minimum quarterly distribution and the target distribution levels, the holders of the incentive distribution rights will be entitled to receive, in the aggregate, the number of common limited partner units equal to that number of common limited partner units which would have entitled the holders to an average aggregate quarterly cash distribution in the prior two quarters equal to the average of the distributions on the incentive distribution rights in the prior two quarters. Our general partner will also be issued the number of general partner units necessary to maintain its general partner interest in us that existed immediately prior to the reset election. We anticipate that our general partner would exercise this reset right in order to facilitate acquisitions or internal growth projects that would not otherwise be sufficiently accretive to cash distributions per common unit. It is possible, however, that our general partner or a transferee could exercise this reset election at a time when it is experiencing, or expects to experience, declines in the cash distributions it receives related to its incentive distribution rights, and may therefore desire to be issued common limited partner units rather than retain the right to receive incentive distribution payments based on target distribution levels that are less certain to be achieved in the then-current business environment. This risk could be elevated if our incentive distribution rights have been transferred to a third party. As a result, a reset election may cause our common unitholders to experience dilution in the amount of cash distributions that they would have otherwise received had we not issued common limited partner units to our general partner or its transferee in connection with resetting the target distribution levels.

Our unitholders' liability may not be limited if a court finds that unitholder action constitutes control of our business.

A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of the partnership that are expressly made without recourse to the general partner. The Partnership is organized under Delaware law, and we conduct business in a number of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearly established in some of the other states in which we do business. Our unitholders could be held liable for any and all of our obligations as if they were general partners if a court or government agency were to determine that:

we were conducting business in a state but had not complied with that particular state’s partnership statute; or
our unitholders' right to act with other unitholders to remove or replace our general partner, to approve some amendments to our Partnership Agreement or to take other actions under our Partnership Agreement constitute “control” of our business.

Unitholders may have liability to repay distributions that were wrongfully distributed to them.

Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 17-607 of the Delaware Revised Uniform Limited Partnership Act, we may not make a distribution to our unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of an impermissible distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnership for the distribution amount. Transferees of common limited partner units are liable both for the obligations of the transferor to make contributions to the Partnership that were known to the transferee at the time of transfer and for those obligations that were unknown if the liabilities could have been determined from the Partnership Agreement. Neither liabilities

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to partners on account of their partnership interest nor liabilities that are non-recourse to the partnership are counted for purposes of determining whether a distribution is permitted.

The NYSE does not require a publicly traded limited partnership like us to comply with certain of its corporate governance requirements.

Our common limited partner units are listed on the New York Stock Exchange ("NYSE"). Because we are a publicly traded limited partnership, the NYSE does not require us to have, and we do not intend to have, a majority of independent directors on our general partner’s board of directors or to establish a compensation committee or a nominating and corporate governance committee. Accordingly, unitholders will not have the same protections afforded to certain corporations that are subject to all of the NYSE corporate governance requirements.

Tax Risks to Common Unitholders
 
Our tax treatment depends on our status as a partnership for federal income tax purposes. If the Internal Revenue Service, or IRS, were to treat us as a corporation for federal income tax purposes, which would subject us to entity-level taxation, then our cash available for distribution to our unitholders would be substantially reduced.

The anticipated after-tax economic benefit of an investment in the common limited partner units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested, and do not plan to request, a ruling from the Internal Revenue Service (the "IRS") on this or any other tax matter affecting us.

Despite the fact that we are a limited partnership under Delaware law, it is possible in certain circumstances for a partnership such as ours to be treated as a corporation for federal income tax purposes. A change in our business or a change in current law could cause us to be treated as a corporation for federal income tax purposes or otherwise subject us to taxation as an entity.

If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 35.0%, and would likely pay state and local income tax at varying rates. Distributions to our unitholders would generally be taxed again as corporate dividends (to the extent of our current and accumulated earnings and profits), and no income, gains, losses, deductions or credits would flow through to such unitholders. Because a tax would be imposed upon us as a corporation, our cash available for distribution would be substantially reduced. Therefore, if we were treated as a corporation for federal income tax purposes, there would be material reductions in the anticipated cash flow and after-tax return to our unitholders, likely causing a substantial reduction in the value of our common limited partner units.

Our Partnership Agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, the minimum quarterly distribution amount and the target distribution amounts may be adjusted to reflect the impact of that law on us.

If we were subjected to a material amount of additional entity-level taxation by individual states, it would reduce our cash available for distribution to our unitholders.

Changes in current state law may subject us to additional entity-level taxation by individual states. Because of widespread state budget deficits and other reasons, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise and other forms of taxation. Imposition of such additional tax on us by a state will reduce the cash available for distribution to our unitholders. Our Partnership Agreement provides that, if a law is enacted or an existing law is modified or interpreted in a manner that subjects us to entity-level taxation, the minimum quarterly distribution amount and the target distribution amounts may be adjusted to reflect the impact of that law on us.

The tax treatment of publicly traded partnerships or an investment in our common limited partner units could be subject to potential legislative, judicial or administrative changes and differing interpretations, possibly on a retroactive basis.

The present federal income tax treatment of publicly traded partnerships, including us, or an investment in our common limited partner units may be modified by administrative, legislative or judicial changes or differing interpretations at any time. From time to time, members of the U.S. Congress propose and consider substantive changes to the existing federal income tax laws that affect publicly traded partnerships. If successful, such a proposal could eliminate the qualifying income exception to the treatment of all publicly traded partnerships as corporations upon which we rely for our treatment as a partnership for federal income tax purposes. We are unable to predict whether any changes or proposals will ultimately be enacted, but it is possible that a change in law could affect us and may, if enacted, be applied retroactively. Any such changes could negatively impact the value of an investment in our common limited partner units. On October 5, 2016, the IRS and the U.S. Department of the Treasury published final, proposed and temporary regulations related to partnership disguised sales, debt basis rules

41



and bottom dollar payment obligations. These regulations have prospective application and do not have a material impact on our historic operations. On January 24, 2017, the IRS and the U.S. Department of the Treasury published final regulations that provide industry-specific guidance regarding whether income earned from certain activities will constitute qualifying income. The final regulations treat as qualifying income the income earned from separating and selling excess renewable identification numbers acquired as part of additization services to comply with environmental regulations.

Our unitholders’ share of our income will be taxable to them for U.S. federal income tax purposes even if they do not receive any cash distributions from us.

Because a unitholder will be treated as a partner to whom we will allocate taxable income, which could be different in amount than the cash we distribute, a unitholder’s allocable share of our taxable income will be taxable to it, which may require the payment of federal income taxes and, in some cases, state and local income taxes on such unitholder's share of our taxable income even if it receives no cash distributions from us. Our unitholders may not receive cash distributions from us equal to their share of our taxable income or even equal to the actual tax liability that results from that income.

If the IRS contests the federal income tax positions we take, the market for our common limited partner units may be adversely impacted and the cost of any IRS contest would likely reduce our cash available for distribution to unitholders.

We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes. The IRS may adopt positions that differ from the conclusions of our counsel or from the positions we take, and the IRS’s positions may ultimately be sustained. It may be necessary to resort to administrative or court proceedings to sustain some or all of our counsel’s conclusions or the positions we take and such positions may not ultimately be sustained. A court may not agree with some or all of our counsel’s conclusions or the positions we take. Any contest with the IRS, and the outcome of any IRS contest, may have a material adverse effect on the market for our common limited partner units and the price at which they trade. In addition, our costs of any contest with the IRS would be borne indirectly by our unitholders and our general partner, because the costs would likely reduce our cash available for distribution.

Tax gain or loss on the disposition of our common limited partner units could be more or less than expected.

If any of our unitholders sells their common limited partner units, such unitholders must recognize a gain or loss for federal income tax purposes equal to the difference between the amount realized and such unitholder's tax basis in those common limited partner units. Because distributions in excess of such unitholder's allocable share of our net taxable income decrease such unitholder's tax basis in such unitholder's common limited partner units, the amount, if any, of such prior excess distributions with respect to the common limited partner units such unitholder sells will, in effect, become taxable income to such unitholder if it sells such common limited partner units at a price greater than its tax basis in those common limited partner units, even if the price such unitholder receives is less than its original cost. Furthermore, a substantial portion of the amount realized on any sale or other disposition of such unitholder's common limited partner units, whether or not representing gain, may be taxed as ordinary income due to potential recapture items, including depreciation recapture. In addition, because the amount realized includes a unitholder’s share of our nonrecourse liabilities, if a unitholder sells their common limited partner units, they may incur a tax liability in excess of the amount of cash they receive from the sale.

Tax-exempt entities and non-U.S. persons face unique tax issues from owning our common limited partner units that may result in adverse tax consequences to them.

Investment in our common limited partner units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (known as IRAs), and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from federal income tax, including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will be reduced by withholding taxes at the highest applicable effective tax rate, and non-U.S. persons will be required to file U.S. federal income tax returns and pay tax on their share of our taxable income. If you are a tax-exempt entity or a non-U.S. person, you should consult a tax advisor before investing in our common limited partner units.

We treat each holder of common limited partner units as having the same tax benefits without regard to the actual common limited partner units held. The IRS may challenge this treatment, which could adversely affect the value of the common limited partner units.

Because we cannot match transferors and transferees of common limited partner units, and because of other reasons, we will adopt depreciation and amortization positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to our unitholders. It also could affect the timing of these tax benefits or the amount of gain from a unitholder's sale of common limited partner units and could have a negative impact on the value of our common limited partner units or result in audit adjustments to such unitholder's tax returns.


42



We prorate our items of income, gain, loss and deduction for U.S. federal income tax purposes between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our unitholders.

We prorate our items of income, gain, loss and deduction for U.S. federal income tax purposes between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The U.S. Department of the Treasury recently adopted final Treasury Regulations allowing a similar monthly simplifying convention for taxable years beginning on or after August 3, 2015. However, such final regulations do not specifically authorize the use of the proration method we have adopted. If the IRS were to challenge our proration method, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders. Our counsel has not rendered an opinion with respect to whether our monthly convention for allocating taxable income and losses is permitted by existing Treasury Regulations.

If the IRS makes audit adjustments to our income tax returns for tax years beginning after 2017, it (and some states) may collect any resulting taxes (including any applicable penalties and interest) directly from us, in which case our cash available for distribution to our unitholders might be substantially reduced.

Pursuant to the Bipartisan Budget Act of 2015, if the IRS makes audit adjustments to our income tax returns for tax years beginning after 2017, it may collect any resulting taxes (including any applicable penalties and interest) directly from us. We will generally have the ability to shift any such tax liability to our general partner and our unitholders in accordance with their interests in us during the year under audit, but there can be no assurance that we will be able to do so (and will choose to do so) under all circumstances, or that we will be able to (or choose to) effect corresponding shifts in state income or similar tax liability resulting from the IRS adjustment in states in which we do business in the year under audit or in the adjustment year. If we make payments of taxes, penalties and interest resulting from audit adjustments, our cash available for distribution to our unitholders would be reduced, perhaps substantially.

A unitholder whose common limited partner units are loaned to a “short seller” to cover a short sale of common limited partner units may be considered as having disposed of those common limited partner units. If so, such unitholder would no longer be treated for federal income tax purposes as a partner with respect to those common limited partner units during the period of the loan and may recognize gain or loss from the disposition.

Because a unitholder whose common limited partner units are loaned to a “short seller” to cover a short sale of common limited partner units may be considered as having disposed of the loaned common limited partner units, such unitholder may no longer be treated for federal income tax purposes as a partner with respect to those common limited partner units during the period of the loan to the short seller and may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of our income, gain, loss or deduction with respect to those common limited partner units may not be reportable by the unitholder, and any cash distributions received by the unitholder as to those common limited partner units could be fully taxable as ordinary income. Therefore, our unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to consult a tax advisor to discuss whether it is advisable to modify any applicable brokerage account agreements to prohibit their brokers from loaning their common limited partner units.

We have adopted certain valuation methodologies and monthly conventions for U.S. federal income tax purposes that may result in a shift of income, gain, loss and deduction between our general partner and our unitholders. The IRS may challenge this treatment, which could adversely affect the value of the common limited partner units.

When we issue additional units or engage in certain other transactions, we determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner. Our methodology may be viewed as understating the value of our assets. In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and our general partner, which may be unfavorable to such unitholders. Moreover, under our valuation methods, subsequent purchasers of common limited partner units may have a greater portion of their Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS may challenge our valuation methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of taxable income, gain, loss and deduction between our general partner and certain of our unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our unitholders. It also could affect the amount of taxable gain from our unitholders’ sale of common limited partner units and could have a negative impact on the value of the common limited partner units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.


43



The sale or exchange of 50% or more of our capital and profits interests during any 12-month period will result in the termination of our Partnership for federal income tax purposes.

We will be considered to have technically terminated our Partnership for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a 12-month period. For purposes of determining whether the 50% threshold has been met, multiple sales of the same interest will be counted only once. Our technical termination would, among other things, result in the closing of our taxable year for all unitholders, which would result in us filing two tax returns (and our unitholders could receive two Schedules K-1 if relief was not available, as described below) for one fiscal year and could result in a deferral of depreciation deductions allowable in computing our taxable income. In the case of a unitholder reporting on a taxable year other than a fiscal year ending December 31, the closing of our taxable year may also result in more than 12 months of our taxable income or loss being includable in such unitholder's taxable income for the year of termination. Our termination currently would not affect our classification as a partnership for federal income tax purposes, but instead we would be treated as a new partnership for tax purposes. If treated as a new partnership, we must make new tax elections and could be subject to penalties if we are unable to determine that a termination occurred. The IRS has announced a publicly traded partnership technical termination relief procedure whereby, if a publicly traded partnership that technically terminated requests publicly traded partnership technical termination relief and such relief is granted by the IRS, among other things, the partnership will only have to provide one Schedule K-1 to unitholders for the year notwithstanding two partnership tax years.

As a result of investing in our common limited partner units, our unitholders may be subject to state and local taxes and return filing requirements in jurisdictions where we operate or own or acquire properties.

In addition to federal income taxes, our unitholders may be subject to other taxes, including state and local income, franchise, unincorporated business, estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we conduct business or own property now or in the future, even if such unitholders do not live or otherwise do business in any of those jurisdictions. Our unitholders may be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, our unitholders may be subject to penalties for failure to comply with those requirements. We currently own property and conduct business in Arkansas, Louisiana, Oklahoma, Tennessee and Texas. Many of these states impose a personal income tax on individuals, and each state imposes an income or similar tax on corporations and certain other entities. As we make acquisitions or expand our business, we may own property or conduct business in additional states that may impose personal income taxes or other state or local taxes on our unitholders.

Compliance with and changes in tax laws could adversely affect our performance.

We are subject to extensive tax laws and regulations, including federal, state and foreign income taxes and transactional taxes such as excise, sales/use, payroll, franchise and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously being enacted that could result in increased tax expenditures in the future. Many of these tax liabilities are subject to audits by the respective taxing authority. These audits may result in additional taxes, as well as interest and penalties.

ITEM 1B.  UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

Our principal assets, as of December 31, 2016, have been described in Item 1—Business—Pipelines and Transportation and Item 1—Business—Wholesale Marketing and Terminalling. We believe that our assets are adequate for our operations and adequately maintained.

Title to Properties and Permits

While we own the physical improvements consisting of our pipelines, substantially all of these pipelines are constructed on rights-of-way granted by the apparent record owners of the property, and in some instances these rights-of-way are revocable at the election of the grantor. In many instances, lands over which rights-of-way have been obtained are subject to prior liens that have not been subordinated to the right-of-way grants. We have obtained permits from public authorities to cross over or under, or to lay facilities in or along, watercourses, county roads, municipal streets and state highways, and, in some instances, these permits are revocable at the election of the grantor. We have also obtained permits from railroad companies to cross over or under lands or rights-of-way, many of which are also revocable at the grantor’s election. In some states and under some circumstances, we have the right of eminent domain to acquire rights-of-way and lands necessary for our common carrier pipelines.

We believe that we are the owner of valid easement rights and rights-of-way or fee ownership or leasehold interests to the lands on which our assets are located. Under the Omnibus Agreement, Delek has agreed to indemnify us for certain title defects and for failures to

44



obtain certain consents and permits necessary to conduct our business, in each case, that are identified prior to the relevant date in the Omnibus Agreement, subject to an annual deductible. Although title to these properties is subject to encumbrances in some cases, such as customary interests generally retained in connection with acquisition of real property, liens that can be imposed in some jurisdictions for government-initiated action to clean up environmental contamination, liens for current taxes and other burdens, and easements, restrictions, and other encumbrances to which the underlying properties were subject at the time of acquisition by our predecessor or us, we believe that none of these burdens should materially detract from the value of these properties or from our interest in these properties or should materially interfere with their use in the operation of our business.

Facilities

Our Nettleton Station and our Bradford Station are located on properties that are owned by third parties in which we have leasehold interests. Our North Little Rock Terminal, our El Dorado Terminal and tank farm, our Tyler Terminal and tank farm, the El Dorado Rail Offloading Racks and the Tyler Crude Tank are located on property leased by third parties, including Delek.

Liens and Encumbrances

The majority of the assets described above are pledged under and encumbered by our credit agreement. See Note 11 of the consolidated financial statements included in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for further information.

Corporate Headquarters

Delek leases its corporate headquarters at 7102 Commerce Way, Brentwood, Tennessee. The lease is for 54,000 square feet and expires in April 2022. We pay Delek a proportionate share of the costs to operate the building pursuant to the Omnibus Agreement. Please read "Item 1—Business—Commercial Agreements—Other Agreements with Delek—Omnibus Agreement."

ITEM 3. 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 currently 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 negotiating a resolution to this matter with the EPA and the State of Arkansas, which may include monetary penalties and/or other relief.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.



PART II

ITEM 5.
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Unit Price and Cash Distributions

Our common units represent limited partner interests in us that entitle the holders to the rights and privileges specified in our Partnership Agreement. Our common units trade on the NYSE under the symbol "DKL." There were three holders of record of our common units held by the public as of February 17, 2017. In addition, as of February 17, 2017, Delek and its affiliates owned 15,077,092 of our common units and 496,502 of our general partner units (the 2% general partner interest), which together constitute a 62.7% ownership interest in us.

The following table sets forth the range of the daily high and low sales prices per common unit for each quarterly period and the cash distributions to common unitholders with respect to each quarterly period during the years ended December 31, 2016 and December 31, 2015.
    

45



Quarter Ended
 
High Sales Price
 
Low Sales Price
 
Quarterly Cash Distribution per Limited Partner Unit (1)   
 
Distribution Date
 
Record Date
December 31, 2016
 
$30.60
 
$21.30
 
$0.680
 
February 14, 2017
 
February 3, 2017
September 30, 2016
 
$29.59
 
$25.20
 
$0.655
 
November 14, 2016
 
November 7, 2016
June 30, 2016
 
$33.92
 
$24.16
 
$0.630
 
August 12, 2016
 
August 5, 2016
March 31, 2016
 
$35.25
 
$21.84
 
$0.610
 
May 13, 2016
 
May 5, 2016
December 31, 2015
 
$38.00
 
$28.05
 
$0.590
 
February 12, 2016
 
February 5, 2016
September 30, 2015
 
$48.46
 
$29.29
 
$0.570
 
November 13, 2015
 
November 6, 2015
June 30, 2015
 
$47.55
 
$30.69
 
$0.550
 
August 14, 2015
 
August 6, 2015
March 31, 2015
 
$44.96
 
$33.30
 
$0.530
 
May 14, 2015
 
May 4, 2015
            
(1) 
Represents cash distributions attributable to the quarter and declared and paid within 45 days of quarter end in accordance with our Partnership Agreement.

Distributions of Available Cash

Our Partnership Agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash to unitholders of record on the applicable record date.
 
Definition of Available Cash

Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter:

less the amount of cash reserves established by our general partner to:

provide for the proper conduct of our business (including cash reserves for our future capital expenditures and anticipated future debt service requirements and refunds of collected rates reasonably likely to be refunded as a result of a settlement or hearing related to FERC rate proceedings or rate proceedings under applicable law subsequent to that quarter);
comply with applicable law, any of our debt instruments or other agreements; or
provide funds for distributions to our unitholders and to our general partner for any one or more of the next four quarters (provided that our general partner may not establish cash reserves for distributions if the effect of the establishment of such reserves will prevent us from distributing the minimum quarterly distribution on all common units and any cumulative arrearages on such common units for the current quarter);
plus, if our general partner so determines, all or any portion of the cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made subsequent to the end of such quarter. Under our Partnership Agreement, working capital borrowings are generally borrowings that are made under a credit facility, commercial paper facility or similar financing arrangement, and in all cases are used solely for working capital purposes or to pay distributions to partners, and with the intent of the borrower to repay such borrowings within 12 months with funds other than from additional working capital borrowings.

Intent to Distribute the Minimum Quarterly Distribution

We intend to pay a quarterly distribution of at least $0.375 per unit per quarter, or $1.50 per unit on an annualized basis, to the extent we have sufficient available cash from our operations after the establishment of cash reserves and the payment of costs and expenses, including reimbursements of expenses to our general partner. However, we do not have a legal obligation to pay this distribution. The amount of distributions paid under our policy, and the decision to make any distribution, is determined by our general partner, taking into consideration the terms of our Partnership Agreement.
 

46



General Partner Interest and Incentive Distribution Rights

Our general partner is currently entitled to 2.0% of all quarterly distributions that we make prior to our liquidation. This general partner interest is represented by 496,502 general partner units. Our general partner has the right, but not the obligation, to contribute up to a proportionate amount of capital to us to maintain its current general partner interest. The general partner’s 2.0% interest in these distributions may be reduced if we issue additional units in the future and our general partner does not contribute a proportionate amount of capital to us to maintain its 2.0% general partner interest.

Our general partner also currently holds incentive distribution rights that entitle it to receive increasing percentages, up to a maximum of 48.0%, of the cash we distribute from operating surplus (as defined in our Partnership Agreement) in excess of $0.43125 per unit per quarter. The maximum distribution of 48.0% does not include any distributions that our general partner or its affiliates may receive on common, subordinated or general partner units that it owns.

Percentage Allocations of Available Cash

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.
 
 
Total Quarterly
 
Marginal Percentage
 
 
Distribution per Unit
 
Interest in Distributions
 
 
Target Amount
 
Unitholders
 
General Partner
Minimum Quarterly Distribution
 
$0.37500
 
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
 
above $0.56250
 
50.0
%
 
50.0
%

47




Expiration of Subordination Period

Following the February 12, 2016 payment of the cash distribution attributable to the fourth quarter of 2015, and confirmation by the board of directors of our general partner (based on the recommendation of the conflicts committee) on February 25, 2016 that the requirements under the Partnership Agreement for the conversion of all subordinated units into common units were satisfied, the subordination period ended. As a result, in the first quarter of 2016, 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 cash distributions paid or the total number of the Partnership's outstanding units representing limited partner interests.

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 during the year ended December 31, 2016. Each sale listed below was exempt from registration under Section 4(a)(2) of the Securities Act.

Date of Sale
 
Number of General Partner Units Sold
 
Price per General Partner Unit
 
Consideration Paid to the Partnership
June 13, 2016
 
530
 
$26.05
 
$13,818
August 23, 2016
 
45
 
$26.20
 
$1,180
November 9, 2016
 
34
 
$21.70
 
$744
December 12, 2016
 
448
 
$30.45
 
$13,634



48



ITEM 6. SELECTED FINANCIAL DATA
 
The following tables set forth certain selected consolidated financial data as of and for each of the five years in the period ended December 31, 2016. The selected historical consolidated financial data for the year ended December 31, 2012 is derived from audited consolidated financial statements of Delek Logistics Partners, LP Predecessor (the "DKL Predecessor"). The selected historical financial data for the 2012 period presented through November 6, 2012 is derived from consolidated financial results of the DKL Predecessor, and the period beginning November 7, 2012 is derived from consolidated financial results of Delek Logistics Partners, LP (the "Partnership"). All financial results have also been adjusted for subsequent transactions with predecessors as noted below.

During the years ended December 31, 2015, 2014 and 2013, the Partnership entered into various transactions with Delek and our general partner pursuant to which we acquired the following assets 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 Refinery (the "El Dorado Refinery")and related ancillary assets (the “El Dorado Assets”) effective March 31, 2015, (such transaction, the "El Dorado Rail Offloading Racks Acquisition");
a crude oil storage tank (the "Tyler Crude Tank") with a shell capacity of approximately 350,000 barrels located adjacent to Delek's Tyler Refinery (the "Tyler Refinery") and certain ancillary assets (collectively, with the Tyler Crude Tank, the "Tyler Assets") effective March 31, 2015, (such transaction, the "Tyler Crude Tank Acquisition"); the Tyler Assets, together with the El Dorado Assets, are hereinafter collectively referred to as the "Logistics Assets."
a refined products terminal (the “El Dorado Terminal”) located at the El Dorado Refinery and (ii) 158 storage tanks and certain ancillary assets (the "El Dorado Tank Assets" and, together with the El Dorado Terminal, the “El Dorado Terminal and Tank Assets”) at and adjacent to the El Dorado Refinery effective February 4, 2014, (such transaction, the “El Dorado Acquisition”).
a refined products terminal (the “Tyler Terminal”) located at the Tyler Refinery and (ii) 96 storage tanks and certain ancillary assets (the "Tyler Tank Assets" and, together with the Tyler Terminal, the “Tyler Terminal and Tank Assets”) adjacent to the Tyler Refinery, effective July 26, 2013 (such transaction, the “Tyler Acquisition”).

The El Dorado Rail Offloading Racks Acquisition, the Tyler Crude Tank Acquisition, the El Dorado Acquisition and the Tyler Acquisition were accounted for as transfers between entities under common control; such acquisitions hereinafter collectively referred to as the "Acquisitions from Delek." As entities under common control with Delek, transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years have been retrospectively adjusted to include the historical results of the assets acquired in the Acquisitions from Delek prior to the effective date of each acquisition for all periods presented. We refer to the DKL Predecessor and, prior to each acquisition date, the Acquisitions from Delek collectively as our “Predecessors.”

Our financial results may not be comparable, as our Predecessors recorded revenues, general and administrative expenses and financed operations differently than the Partnership. See "Factors Affecting the Comparability of Our Financial Results" in Management's Discussion and Analysis of Financial Condition and Results of Operations in Item 7 for additional information.

The following tables should be read in conjunction with Management's Discussion and Analysis of Financial Condition and Results of Operations in Item 7 and our consolidated financial statements in Item 8.

49




 
 
Year Ended December 31,
 
 
2016
 
2015
 
2014
 
2013
 
2012 (1)
 
 
 
 
 
 
 
 
 
 
Predecessors
Statements of Income and Other Comprehensive Income Data:
 
 
 
(In thousands, except units and per unit data)
 
 
Net sales
 
$
448,059

 
$
589,669


$
841,253


$
907,428


$
1,022,586

Operating costs and expenses
 
370,409

 
512,407

 
762,407


868,697


1,020,062

Operating income
 
77,650

 
77,262

 
78,846


38,731


2,524

Non-operating costs and expenses
 
14,765

 
11,246

 
8,656

 
4,570

 
2,682

Income (loss) before income tax (benefit) expense
 
62,885

 
66,016

 
70,190

 
34,161

 
(158
)
Income tax expense (benefit)
 
81

 
(195
)
 
132

 
757

 
(14,024
)
Net income

62,804

 
66,211

 
70,058

 
33,404

 
13,866

Less: (Loss) income attributable to Predecessors
 

 
(637
)
 
(1,939
)
 
(14,426
)
 
5,456

Net income attributable to partners
 
$
62,804

 
$
66,848

 
$
71,997

 
$
47,830

 
$
8,410

 
 
 
 
 
 
 
 
 
 
 
Less: General partners' interest in net income (2%)

12,193

 
5,163

 
2,366

 
957

 
 
Limited partners' interest in net income

$
50,611

 
$
61,685

 
$
69,631

 
$
46,873

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

$
2.08

 
$
2.55

 
$
2.88

 
$
1.95

 
 
Common - (diluted)
 
$
2.07

 
$
2.52

 
$
2.85

 
$
1.93

 
 
Subordinated - Delek (basic and diluted)
 
$
2.19

 
$
2.54

 
$
2.88

 
$
1.95

 
 
Weighted average limited partner units outstanding:
 
 

 
 

 
 
 
 
 
 
Common units - (basic)
 
22,490,264

 
12,237,154

 
12,171,548

 
12,025,249

 
 
Common units - (diluted)
 
22,558,717

 
12,356,914

 
12,302,629

 
12,148,774

 
 
Subordinated units - Delek (basic and diluted)
 
1,803,167

 
11,999,258

 
11,999,258

 
11,999,258

 
 
            

(1) 
The information presented includes the results of operations of our Predecessors. Prior to the completion of the Offering and subsequent acquisitions from Delek, our Predecessors did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

 
 
Year Ended December 31,
 
 
2016
 
2015
 
2014
 
2013
 
2012
 
 
 
 
 
 
 
 
 
 
Predecessors
Balance Sheet Data:
 
 
 
(In thousands)
 
 
Property, plant and equipment, net
 
$
251,029

 
$
253,848

 
$
254,779

 
$
242,512

 
$
220,566

Total assets
 
415,547

 
375,288

 
331,286

 
319,350

 
312,825

Total debt, including current maturities
 
392,600

 
351,600

 
251,750

 
164,800

 
90,000

Total liabilities
 
428,831

 
386,306

 
291,505

 
214,142

 
146,092

Total (deficit) equity
 
(13,284
)
 
(11,018
)
 
39,781

 
105,208

 
166,733







50



ITEM 7. 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 February 10, 2014, the Partnership, through its wholly owned subsidiary Delek Logistics Operating, LLC ("OpCo"), acquired from Delek (i) the refined products terminal (the “El Dorado Terminal”) located at Delek's El Dorado, Arkansas refinery (the "El Dorado Refinery") and (ii) 158 storage tanks and certain ancillary assets (the "El Dorado Tank Assets" and, together with the El Dorado Terminal, the “El Dorado Terminal and Tank Assets”) at and adjacent to the El Dorado Refinery (such transaction, the “El Dorado Acquisition”).

On March 31, 2015, the Partnership, through OpCo, 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 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 Acquisition, 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 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: (i) the historical results of the El Dorado Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through February 10, 2014 (the "El Dorado Predecessor"), (ii) the historical results of the El Dorado Assets, as owned and operated by Delek, for all periods presented through March 31, 2015 (the "El Dorado Assets Predecessor") and (iii) the historical results of the Tyler Assets, as owned and operated by Delek, for all periods presented 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." We refer to the historical results of the El Dorado Predecessor, the El Dorado Assets Predecessor and the Tyler Assets Predecessor collectively as our "Predecessors."

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

Forward-Looking Statements

This Annual Report on Form 10-K contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 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, the benefits and synergies to be obtained from our completed and any future acquisitions, 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.


51



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 with 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 ("FERC") 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;
an inability of Delek 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 and regulations;
the effects of future litigation; and
other factors discussed elsewhere in this Annual Report on Form 10-K for the year ended December 31, 2016.

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.


52



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 such 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 the partner's units and the taxable income allocation requirements under the Partnership's First Amended and Restated Agreement of Limited Partnership (the "Partnership Agreement").

Recent Developments

Paline Pipeline Hydro Test.  In August 2016, we successfully completed a hydro test on our Paline Pipeline. See Item 1, "Business—2016 Developments—Paline Pipeline Hydro Test" for additional information on this test.

Inflation Adjustments. The tariffs on our pipelines and the throughput and storage fees under our agreements with Delek and third parties are subject to increase or decrease annually, by the amount of any change in various inflation-based indices, including the FERC oil pipeline index, the consumer price index and the producer price index. See Item 1, "Business—2016 Developments—Inflation Adjustments" for additional information on these changes.

Subordinated Unit Conversion. 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 5 and 12 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for additional information.

Joint Ventures. During 2016, we substantially completed construction of assets held by two joint ventures with unrelated third parties. These assets include the following:

an 80-mile crude oil pipeline with a capacity of 80,000 bpd that originates in Longview, Texas with destinations in the Shreveport, Louisiana area (the "Caddo Pipeline"); and
a 107-mile crude oil pipeline with a capacity of 55,000 bpd with the capability to expand to 85,000 bpd, that originates in north Loving County, Texas near the Texas-New Mexico border and terminates in Midland, Texas (the "RIO Pipeline").

The joint venture that owns the Caddo Pipeline was formed pursuant to an agreement between our subsidiary DKL Caddo, LLC ("DKL Caddo") and Plains Pipeline, L.P., an affiliate of Plains All American Pipeline, L.P. ("Plains"), under which DKL Caddo and Plains each own a 50% membership interest. Operations on the Caddo Pipeline began in January 2017.

The joint venture that owns 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. Operations on the RIO Pipeline began in September 2016.

Business Strategies

Our objectives are to maintain stable cash flows and to grow the quarterly distributions paid to our unitholders over time. We are focused on growing our asset base within our geographic area through acquisitions, project development, joint ventures and enhancing our existing systems. While we will continue to evaluate ways to provide Delek with logistics services, our emphasis will be to increase the logistics services that we offer to third parties. We intend to achieve these objectives through the following business strategies:


53



Generate Stable Cash Flow. We will continue to pursue opportunities to provide logistics, marketing and other services to Delek and third parties pursuant to long-term, fee-based contracts. In new service contracts, we will endeavor to include minimum volume throughput, or other commitments, similar to those included in our current commercial agreements with Delek.

Focus on Growing Our Business. We intend to evaluate and pursue opportunities to grow our business through both strategic acquisitions and expansion and construction projects, both internally funded or in combination with potential external partners. We believe that our strong relationship with Delek will enhance our opportunities to grow our business.

Pursue Acquisitions. We plan to pursue strategic acquisitions that both complement our existing assets and provide attractive returns for our unitholders. As we continue to grow through acquisitions, we believe we will be able to increase our third party business.

Additionally, Delek has granted us a right of first offer on certain logistics assets. We intend to review our right to purchase any such assets as they are offered to us under the terms of the right of first offer, from time to time. Delek is also required, under certain circumstances, to offer us the opportunity to purchase additional logistics assets that Delek may acquire or construct in the future. In addition to those opportunities to acquire assets from Delek, we believe that our current asset base, and our knowledge of the regional markets in which we operate, will enable us to target and complete attractive third-party acquisitions.

Pursue Attractive Expansion and Construction Opportunities. We intend to pursue organic growth opportunities that complement our existing businesses or that provide attractive returns within or outside our current geographic footprint. We plan to evaluate potential opportunities to make capital investments that will be used to expand our existing asset base through the expansion and construction of new logistics assets to support growth of any of our customers', including Delek's, businesses and from increased third-party activity. These construction projects may be developed either through joint venture relationships or by us acting independently, depending on size and scale. For example, in March 2015, we entered into two joint ventures to construct logistics assets. Construction on these assets was substantially completed in September 2016 and January 2017.

Optimize Our Existing Assets and Expand Our Customer Base. We seek to enhance the profitability of our existing assets by adding incremental throughput volumes, improving operating efficiencies and increasing system-wide utilization. We also expect to further diversify our customer base by increasing third-party throughput volumes running through certain of our existing systems and expanding our existing asset portfolio to service more third-party customers.

Commercial Agreements

The Partnership has a number of long-term, fee-based commercial agreements with Delek under which we provide various services, including crude oil gathering and crude oil, intermediate and refined products transportation and storage services, and marketing, terminalling and offloading services to Delek, 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 Note 4 to the consolidated financial statements in Item 8, Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for a discussion of our material 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:

54



 
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 goods sold) 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. In the third quarter of 2016, we revised our definition of distributable cash flow to include the reconciliation of this non-GAAP measure from U.S. GAAP net cash from operating activities rather than from EBITDA. Distributable cash flow is derived from net cash flow from operating activities plus or minus changes in assets and liabilities, less maintenance capital expenditures net of reimbursements and other adjustments not expected to settle in cash. We believe this revision is a more appropriate reflection of a liquidity measure by which users of our financial statements can assess our ability to generate cash. Additionally, 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 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 flow from operating activities 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 and distributable cash flow may not be comparable

55



to similarly titled measures of other companies, thereby diminishing its utility. For a reconciliation of EBITDA and distributable cash flow to its most directly comparable financial measures calculated and presented in accordance with U.S. GAAP, please refer to "—Results of Operations."

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 Predecessors recorded revenues and the way the Partnership records revenues after the Acquisitions from Delek. Because our assets, including the Logistics Assets and the El Dorado Terminal and Tank Assets, were historically a part of the integrated operations of Delek, the Predecessors 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 Predecessors' consolidated financial statements are different than those reflected in the Partnership's consolidated financial statements, as the Predecessors' 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 Predecessors' 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 Predecessors 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 4 to our 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 paid a cash distribution to its unitholders at a distribution rate of $0.68 per unit for the quarter ended December 31, 2016 ($2.72 per unit on an annualized basis). Our 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 year ended December 31, 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, depressed crude oil prices and the prices of related refined products 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 many crude oil pipelines in the United States and limited the need for new infrastructure projects. Second, the credit markets have become less liquid in the energy sector during this ongoing period of depressed prices, which has reduced the availability of credit and increased the cost of debt. Third, due to the 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 limits the ability to develop profitable growth projects that are needed to support future distribution growth in the midstream energy sector. More recently, however, including in the latter half of 2016, market conditions have begun to improve. The prices of crude oil and related refined products have increased throughout the year. Additionally, drilling activity, particularly in the Permian basin, has escalated as a result of increasing prices and the discovery of a large oil deposit in the area. As market conditions improve and demand benefits from increased drilling activity, we expect our operations to benefit from the trend and have a corresponding improvement, particularly in the west Texas area where we are most susceptible to the effects of market factors.



56



West Texas Marketing Operations

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. However, as discussed above, both drilling activity and the prices of crude oil and related refined products have recently begun to increase. See below for the high, low and average price per barrel of WTI crude oil for each of the quarterly periods during the years ended December 31, 2016, 2015 and 2014.

dkl-10kx1231_chartx44058.jpg





Also, the volatility of finished products prices may impact 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 during the years ended December 31, 2016, 2015 and 2014.


57



dkl-10kx1231_chartx46317.jpg
dkl-10kx1231_chartx48355.jpg






58




Our west Texas operations can 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 $6.7 million, $5.8 million and $4.4 million of RINs to Delek during the years ended December 31, 2016, 2015 and 2014, respectively. See below for the high, low and average prices of RINs for each of the quarterly periods during the years ended December 31, 2016, 2015 and 2014.

dkl-10kx1231_chartx50052.jpg

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. 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.

Results of Operations

A discussion and analysis of the factors contributing to our results of operations is presented below. The accompanying consolidated financial statements and related notes of the Partnership have been retrospectively adjusted to include the historical results of the El Dorado Terminal and Tank Assets for all periods presented through February 10, 2014 and the historical results of the Logistics Assets for all periods presented through March 31, 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.

59




The following table and discussion present a summary of our consolidated results of operations for the years ended December 31, 2016, 2015 and 2014, including a reconciliation of EBITDA to net income and distributable cash flow to net cash provided by operating activities (in thousands, except unit and per unit amounts). Our financial results may not be comparable, as our Predecessors recorded revenues, general and administrative expenses and financed operations differently than the Partnership. See "—Factors Affecting the Comparability of Our Financial Results" for additional information.

Statements of Income and Comprehensive Income Data
(In thousands, except unit data and per unit data)
 
 
 
 
 
 
 

 
Years ended December 31,
 
 
2016
 
2015
 
2014
Net sales:
 
 
 
 
 
 
  Pipelines and transportation
 
$
122,172

 
$
131,379

 
$
91,348

  Wholesale marketing and terminalling
 
325,887

 
458,290
 
749,905
     Total
 
448,059

 
589,669
 
841,253
Operating costs and expenses:
 
 
 
 
 
 
  Cost of goods sold
 
302,158

 
436,304
 
697,221
  Operating expenses
 
37,198

 
44,923
 
39,465
  General and administrative expenses
 
10,256

 
11,384
 
10,616
  Depreciation and amortization
 
20,813

 
19,692
 
15,022
  (Gain) loss on asset disposals
 
(16
)
 
104

 
83

     Total operating costs and expenses
 
370,409
 
512,407
 
762,407
Operating income
 
77,650

 
77,262
 
78,846
Interest expense, net
 
13,587

 
10,658
 
8,656

Loss on equity method investments
 
1,178

 
588

 

     Total non-operating costs and expenses
 
14,765

 
11,246

 
8,656

Income before income tax expense (benefit)
 
62,885

 
66,016

 
70,190

Income tax expense (benefit)
 
81

 
(195
)
 
132

Net income
 
62,804

 
66,211

 
70,058

Less: Loss attributable to Predecessors
 

 
(637
)
 
(1,939
)
Net income attributable to partners
 
$
62,804

 
$
66,848

 
$
71,997

Comprehensive income attributable to partners
 
$
62,804

 
$
66,848

 
$
71,997

EBITDA (1)
 
$
97,285

 
$
96,366

 
$
93,868

 
 


 
 
 
 
Less: General partner's interest in net income (2%), including incentive distribution rights
 
12,193

 
5,163

 
2,366

Limited partner's interest in net income
 
$
50,611

 
$
61,685

 
$
69,631

 
 
 
 
 
 
 
Net income per limited partner unit (2):
 
 
 
 
 
 
     Common units - (basic)
 
$
2.08

 
$
2.55

 
$
2.88

     Common units - (diluted)
 
$
2.07

 
$
2.52

 
$
2.85

     Subordinated units - Delek (basic and diluted)
 
$
2.19

 
$
2.54

 
$
2.88

 
 
 
 
 
 
 
Weighted average limited partner units outstanding (2):
 
 
 
 
 
 
     Common units - (basic)
 
22,490,264

 
12,237,154

 
12,171,548
     Common units - (diluted)
 
22,558,717

 
12,356,914

 
12,302,629
     Subordinated units - Delek (basic and diluted)
 
1,803,167

 
11,999,258

 
11,999,258

60



            
(1) 
For a definition of EBITDA , see "—How We Evaluate Our Operations—EBITDA and Distributable Cash Flow."
(2) 
We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period. The weighted-average number of common and subordinated units reflects the conversion of the subordinated units to common units on February 25, 2016. See Notes 5 and 12 to our accompanying consolidated financial statements for further discussion.


(in thousands)
 
Years Ended December 31,
 
 
2016
 
2015 (2)
 
2014 (3)
Reconciliation of net income to EBITDA:
 
 
 
 
 
 
Net income
 
$
62,804

 
$
66,211

 
$
70,058

Add:
 
 
 
 
 
 
Income tax expense (benefit)
 
81

 
(195
)
 
132

Depreciation and amortization
 
20,813

 
19,692

 
15,022

       Interest expense, net
 
13,587

 
10,658

 
8,656

EBITDA (1)
 
$
97,285

 
$
96,366

 
$
93,868

 
 
 
 
 
 
 
Reconciliation of net cash from operating activities to distributable cash flow:
 
 
 
 
 
 
Net cash provided by operating activities
 
$
100,707

 
$
68,024

 
$
85,084

Changes in assets and liabilities
 
(14,861
)
 
20,106

 
(1,234
)
Maintenance and regulatory capital expenditures (4)
 
(5,920
)
 
(11,841
)
 
(6,642
)
Reimbursement from Delek for capital expenditures (5) 
 
1,880

 
5,220

 
1,578

Accretion of asset retirement obligations
 
(266
)
 
(251
)
 
(232
)
Deferred income taxes
 
173

 
(14
)
 
109

Gain (loss) on asset disposals
 
16

 
(104
)
 
(83
)
Distributable cash flow (1)
 
$
81,729

 
$
81,140

 
$
78,580


(1) 
For a definition of EBITDA and distributable cash flow, see "—How We Evaluate Our Operations—EBITDA and Distributable Cash Flow."
(2) 
EBITDA and distributable cash flow include net loss of $0.2 million related to the Logistics Assets Predecessor during the year ended December 31, 2015.
(3) 
EBITDA and distributable cash flow include net loss of $1.5 million related to our Predecessors for the year ended December 31, 2014.
(4) 
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.
(5) 
For the years ended December 31, 2016, 2015 and 2014, Delek reimbursed us for certain capital expenditures pursuant to the terms of the Omnibus Agreement (as defined in Note 4 to our consolidated financial statements).











61




Segment Data:

The following is a summary of business segment capital expenditures for the periods indicated (in thousands):
 
 
 
Year Ended December 31,
 
 
2016
 
2015
 
2014
 Capital spending (excluding business combinations)
 
 
 
 
 
 
     Pipelines and Transportation
 
$
8,478

 
$
16,030

 
$
5,804

    Wholesale Marketing and Terminalling
 
3,289

 
6,397

 
3,364

          Total capital spending
 
$
11,767

 
$
22,427

 
$
9,168

 

62




Consolidated Results of Operations - Comparison of the Year Ended December 31, 2016 versus the Year Ended December 31, 2015 and the Year Ended December 31, 2015 versus the Year Ended December 31, 2014

The following table presents a summary of our consolidated results of operations and our segment operating performance for the years ended December 31, 2016, December 31, 2015 and December 31, 2014 (in thousands).

 
 
 
Year Ended December 31,
 
 
2016
 
2015
 
2014
Pipelines and Transportation
 
 
 
 
 
 
Net sales:
 
 
 
 
 
 
   Affiliate
 
103,749

 
$
102,551

 
80,683

   Third-Party
 
18,423

 
28,828

 
10,665

     Total Pipelines and Transportation
 
122,172

 
131,379