EX-99.1 2 ex991dklmay2020investorp.htm EXHIBIT 99.1 INVESTOR PRESENTATION 5.21.20
Investor Presentation May 2020

Disclaimers Forward Looking Statements: Delek US Holdings, Inc. (“Delek US”) and Delek Logistics Partners, LP (“Delek Logistics”; and collectively with Delek US, “we” or “our”) are traded on the New York Stock Exchange in the United States under the symbols “DK” and ”DKL”, respectively. These slides and any accompanying oral and written presentations contain forward-looking statements within the meaning of federal securities laws that are based upon current expectations and involve a number of risks and uncertainties. Statements concerning current estimates, expectations and projections about future results, performance, prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under the federal securities laws. These forward-looking statements include, but are not limited to, the statements regarding the following: financial and operating guidance for future and uncompleted financial periods; financial strength and flexibility; potential for and projections of growth; return of cash to shareholders, stock repurchases and the payment of distributions, including the amount and timing thereof; projections of distribution coverage, leverage ratios, financial flexibility and borrowing capacity; crude oil throughput; crude oil market trends, including production, quality, pricing, demand, imports, exports and transportation costs; pipeline takeaway capacity and projects related thereto; the ability to add flexibility and increase margin potential at the Krotz Springs refinery; the performance of our joint venture investments, including Red River and Wink to Webster, and the benefits, flexibility, returns and EBITDA therefrom; our ability to execute on the Big Spring Gathering System and the benefits, flexibility, returns and EBITDA therefrom; the potential for, and estimates of cost savings and other benefits from, acquisitions, divestitures, dropdowns and financing activities; retail growth and the opportunities and value derived therefrom; long-term value creation from capital allocation; execution of strategic initiatives and the benefits therefrom; and access to crude oil and the benefits therefrom. 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. Investors are cautioned that the following important factors, among others, may affect these forward-looking statements: our substantial dependence on Delek US, thereby subjecting us to Delek US' business risks; risks and costs relating to the age and operational hazards of our assets including, without limitation, costs, penalties, regulatory or legal actions and other effects related to releases, spills and other hazards inherent in transporting and storing crude oil and intermediate and finished petroleum products; the impact of adverse market conditions affecting the utilization of Delek Logistics' assets and business performance, including margins generated by its wholesale fuel business; the impact of the COVID-19 outbreak on the demand for crude oil, refined products and transportation and storage services; uncertainties regarding future decisions by OPEC regarding production and pricing disputes between OPEC members and Russia; an inability of Delek US to grow as expected as it relates to our potential future growth opportunities, including dropdowns, and other potential benefits; the results of our investments in joint ventures; the ability of the Red River joint venture to complete the expansion to increase the Red River pipeline capacity; the ability of the Wink to Webster joint venture to construct the long-haul pipeline; the ability to grow the Big Spring Gathering System; general economic and business conditions affecting the geographic areas in which we operate; adverse changes in laws including with respect to tax and regulatory matters; and and other risks disclosed in Delek US’ and Delek Logistics’ filings with the United States Securities and Exchange Commission. Forward-looking statements should not be read as a guarantee of future performance or results, and will not 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. Neither Delek US nor Delek Logistics undertakes any obligation to update or revise any such forward-looking statements. Non-GAAP Disclosures: Delek US and Delek Logistics believe that the presentation of distributable cash flow (“DCF”), earnings before interest, taxes, depreciation and amortization ("EBITDA") and adjusted EBITDA provide useful information to investors in assessing their financial condition, results of operations and cash flow their business is generating. DCF, EBITDA and adjusted EBITDA should not be considered as alternatives to net income, operating income, cash from operations or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP. DCF, EBITDA and adjusted EBITDA have important limitations as analytical tools because they exclude some, but not all, items that affect net income. Additionally, because DCF, EBITDA and adjusted EBITDA may be defined differently by other companies in its industry, Delek US' and Delek Logistics’ definitions may not be comparable to similarly titled measures of other companies, thereby diminishing their utility. Please see reconciliations of DCF, EBITDA and adjusted EBITDA to their most directly comparable financial measures calculated and presented in accordance with U.S. GAAP in the appendix. 2

Investment Overview • Current Distribution: $0.89/LP unit qtr.; $3.56/LP unit annualized (1) Overview (NYSE: DKL) • Visibility for distribution coverage in the range of 1.4x to 1.5x and a leverage ratio below 4.0x by the end of 2020 • Net Income of $27.8 million, Net cash from operating activities $34.8 million • Distributable Cash Flow $35.5 million; DCF coverage ratio 1.15x (2) 1Q20 Highlights • EBITDA of $48.7 million (2) • Quarterly distribution increased by 8.5% year-over-year • $155 million credit available at March 31, 2020 Balance Sheet • Leverage ratio of 4.15x as of March 31, 2020 • Strategic focus on organic projects, supporting coverage and reducing leverage • Red River joint venture with Plains in May 2019; $128.0 million investment + approx. $16.0 million for expansion Growth Provided by Red River • Expected annualized adjusted EBITDA of $13.5 to $15.5 million pre-expansion and Paline Pipeline growing to $20.0 to $25.0 million post-expansion (second half 2020) (2) • Supports additional crude flexibility in the Delek US refining system • Paline tariff increased Feb. 28, 2019; expected $900,000/mo adjusted EBITDA benefit (2) • DK dropped Big Spring Gathering System on March 31, 2020 Recent Dropdowns of Big Spring • Expected $30 - $32 million Annual EBITDA underpinned by MVC DK to DKL(2) • DK dropped trucking assets to DKL effective May 1, 2020 Gathering and Trucking Assets • Expected $8-9 million Annual EBITDA underpinned by MRC DK to DKL(2) (1) Annualized distribution based on quarterly distribution for quarter ended March 31, 2020 paid on May 12, 2020 to unitholders of record on May 5, 2020. (2) For reconciliation to U.S. GAAP please refer to pages 33 for distributable cash flow (“DCF”) coverage ratio, 34 for DKL EBITDA, 36 for Paline EBITDA, 37 for Red River, 38 for Big Spring Gathering, and 39 for Trucking Assets 3

Delek US – A Growth Oriented, Financially Strong Partner • 302,000 bpd of refining capacity in Texas, Arkansas, Louisiana Operational Strength • Access to crude / product terminals, pipeline and storage assets Financial Strength • At Mar. 31, 2020 Delek US had a $1.3 billion debt position excluding DKL and approx. $781 million in cash (1) • Doubled in size in July 2017 with acquisition of Alon USA; Increased Permian Basin position and logistics asset base Growth Oriented • Announced midstream growth projects to be developed by Delek US – Big Spring Gathering System and investment in Wink to Webster joint venture long haul crude oil pipeline Strategically Located Refineries Provide Crude Oil Supply Flexibility and Broad Product Distribution Refining • 302,000 bpd in total • El Dorado, AR • Tyler, TX • Big Spring, TX • Krotz Springs, LA • Crude oil supply: 262,000 bpd WTI linked (207,000 bpd of Permian access) Logistics (2) Retail • 10 terminals • Approximately 252 • Approx. 1,290 mi of pipeline stores • 11.4 million bbls of storage capacity • Southwest US locations • West Texas wholesale • West Texas wholesale • Joint venture crude oil pipelines: RIO / marketing business Caddo / Red River • Own 63.4%, incl. 2% GP, of DKL 1) Data presented as of March 31, 2020 financial statements in the Delek US SEC quarterly filing. 2) Consists of ownership in Delek Logistics. 4

Delek US - Distinguishing Characteristics 1) Source: Platts and NYMEX as of May 5, 2020 5

DKL Relative to Peer Group Where We Are and Where We Are Going 1Q20 Distribution Coverage Yr/Yr Distribution Growth Visibility for distribution coverage in the range of 1.4x to 1.5x 8.5% by the end of 2020 6.2% 3.6% 2.2% 1.7% DKL MPLX PSXP MMP EPD PBFX HEP PAA 2.16x 2.00x 1.67x 1.52x 1.40x 1.26x 1.15x 0.91x 1.45x -41.2% PBFX PAA EPD MMP MPLX PSXP DKL HEP DKL: YE -47.8% 2020 -50.0% Forecast 1Q20 Leverage Ratio Current Dividend Yield Visibility for leverage ratio below 4.0x by the end of 2020 2.70x 2.99x 3.09x 3.39x 3.91x 4.15x 4.34x 4.84x <4.0x PSXP MMP PAA EPD PBFX DKL HEP MPLX DKL: YE 17.6% 14.3% 12.8% 9.8% 9.5% 9.0% 8.1% 7.9% 2020 Forecast DKL MPLX PBFX EPD MMP HEP PAA PSXP (1) Updated from Factset as of May 18, 2020. 6

Delek Logistics Partners, LP Overview

Logistics Assets Positioned to Benefit from Permian Basin Activity Growing logistics assets support crude sourcing and product marketing for customers Pipelines/Transportation Segment • ~805 miles (1) of crude and product transportation pipelines, including the 195 mile crude oil pipeline from Longview to Nederland, TX • ~ 600 mile crude oil gathering system in AR • Storage facilities with 10 million barrels of active shell capacity • Rail offloading facility Wholesale/Terminalling Segment • Wholesale and marketing business in west Texas • 10 light product terminals: in TX, TN, AR • Approx. 1.4 million barrels of active shell capacity (1) Includes approximately 240 miles of leased pipeline capacity. 8

Delek Permian Gathering East System Equipment DPG East System Lease Automatic Custody 45 Installations Transfer Units (LACTS) Pipeline 60 miles Tanks (bbl) 2 (50M, 300M) 9

Delek Permian Gathering West System DPG West System Equipment Lease Automatic Custody 6 Transfer Units (LACTS) Installations Pipeline 70 miles Tanks (bbl) 1 (50M) 10

Multi-Year Contracts with Firm Commitments / MVCs (1) Duration of Contracts as of 1Q20 & Pro-Forma Drops Contract Highlights • The Lion Pipeline System and SALA Gathering System are < 1 Year < 1 Year 20% 18% 26% supported by a long-term contract that includes three take- 1 to 3 Years 1 to 3 Years 31% or-pay commitments 3 to 5 Years 3 to 5 Years > 5 Years > 5 Years • Initial term of 5 years, maximum term of 15 years (2) 54% 50% 68% of 1Q20 Gross Margin from Minimum Volume • Crude oil transportation throughput of 55 MBbl/d in Commitments (MVCs); ~70 - 75% Pro-Forma Q1 2020, supported by a MVC of 46 MBbl/d (3) $64 $65 • Refined products transportation throughput of 54 $62 $60 $59 $58 MBbl/d in Q1 2020, supported by a MVC of 40 $60 $56 $57 $13 $13 $11 (7) $14 $11 $11 MBbl/d $50 $49 $11 $11 $45 $8 $8 $9 $5 $4 $42 $41 $5 $2 $3 $39 $12 • Crude oil gathering throughput of 35 MBbl/d in Q1 $40 $37 $37 $36 $7 $13 $1 $3 $34 $9 2020, supported by a MVC of 14 MBbl/d $4 $3 $5 $4 $4 $2 $5 $ $ in millions $30 $4 $4 $3 $5 $5 • East Texas Wholesale Marketing: contractual agreement with $20 DK with MVC of 50 MBbl/d $10 • Big Spring marketing agreement: contractual agreement with $32 $31 $28 $28 $29 $30 $28 $27 $32 $42 $43 $43 $43 $43 $43 $44 $42 $0 DK with MVC of 65 MBbl/d 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 (6) (4) (5) Contracted Min Gross Margin Contracted Excess Gross Margin Uncontracted Gross Margin 1) Based on percentage of 1Q20 gross margin earned from contracts. Duration excludes automatic renewal at Delek US’ option in future periods. 2) Maximum term assumes an extension of the commercial agreement pursuant to terms thereof. Please note that some terms began as early as November 7, 2012. 3) Volumes gathered on the SALA Gathering System will not be subject to an additional fee for transportation on the Lion Pipeline System. 4) Gross margin generated from the minimum volume commitment provisions of each contract. 5) Gross margin generated by throughput volumes above the minimum volume commitment provision of each contract. 6) Gross margin generated by assets without contracts. 11

Financial Flexibility and Growing Distributable Cash Flow Solid Net Income and EBITDA performance (1) $190.0 $178.9 $188.3 $140.0 $164.0 $90.0 $115.0 $104.9 $97.3 $90.2 $96.8 $ in millions $ in $40.0 $62.8 $69.4 -$10.0 2016 2017 2018 2019 2020 LTM (3) Net Income EBITDA DCF supports distribution growth (2) Financial Flexibility to support continued growth $160.0 $1,200 $140.0 $1,100 $1,000 $107.0 $120.0 $133.4 $316.8 $253.0 $253.7 $261.6 $126.9 $900 $393.3 $388.8 $121.6 $205.3 $206.1 $100.0 $800 $700 $511.1 $80.0 $600 $743.0 $597.7 $83.0 $85.0 $533.2 $596.3 $588.4 $60.0 $500 $494.7 $493.9 $456.7 $461.2 $ in millions $ in $ in millions $ in $400 $40.0 $300 $179.9 $200 $20.0 $100 $242.7 $243.0 $243.3 $243.5 $243.7 $244.0 $253.3 $244.5 $244.7 $244.7 $0.0 $0 (3) (4) 2016 2017 2018 2019 2020 LTM Distributable Cash Flow Revolver Excess Capacity Revolver Borrowings $250 million 6.75% Sr. Notes (net of discount/fees) 1) Reconciliation of EBITDA to Net Income provided on page 34. Excluded are predecessor costs related to the crude oil storage tank and rail offloading racks acquired in March 2015. 2) Reconciliation distributable cash flow to net cash from operating activities on page 33. 3) Last 12 months as of March 31, 2020. 4) Revolver Capacity following the dropdown of the trucking assets announced May 14, 2020. 12

Increased Distribution with Conservative Coverage and Leverage Distribution per unit has increased twenty-nine consecutive times since the IPO $0.385 $0.395 $0.405 $0.415 $0.425 $0.475 $0.490 $0.510 $0.530 $0.550 $0.570 $0.590 $0.610 $0.630 $0.655 $0.680 $0.690 $0.705 $0.715 $0.725 $0.750 $0.770 $0.790 $0.810 $0.820 $0.850 $0.880 $0.885 $0.890 (1) 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 Distributable Cash Flow Coverage Ratio (2)(3)(4) Avg. 1.68x in 2014 Avg. 1.35x in 2015 Avg. 1.35x in 2013 Avg. 1.11x in 2016 Avg. 1.19x in 2018 Avg. 0.97x in 2017 Avg. 1.08x in 2019 1.39x 1.32x 1.35x 1.30x 1.61x 2.02x 1.42x 1.67x 1.25x 1.49x 1.47x 1.18x 1.20x 1.29x 0.98x 1.00x 0.88x 1.06x 0.97x 0.96x 1.14x 1.34x 1.25x 1.03x 1.06x 1.08x 1.11x 1.08x 1.15x 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 Leverage Ratio (4) 1.70x 1.58x 2.28x 2.40x 3.21x 2.69x 2.55x 2.56x 3.00x 3.14x 3.11x 3.49x 3.48x 3.47x 3.70x 3.85x 3.83x 3.88x 3.72x 3.77x 4.60x 4.44x 4.53x 4.08x 4.17x 4.60x 4.60x 4.43x 4.15x 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 1) MQD = minimum quarterly distribution set pursuant to the Partnership Agreement. 2) Distribution coverage based on distributable cash flow divided by distribution amount in each period. Please see reconciliations starting on page 33. 3) In 4Q17, the reimbursed capital expenditure amounts in the determination of distributable cash flow were revised to reflect the accrual of reimbursed capital expenditures from Delek rather than the cash amounts received for reimbursed capital expenditures during the years ended December 31, 2017, 2016 and 2015. 4) Leverage ratio based on LTM EBITDA as defined by credit facility covenants for respective periods. 13

DKL Asset & Joint Venture Detail

Joint Venture Pipeline Projects Create platforms for future growth; Ability to leverage Permian position RIO Pipeline (Delaware Basin) • MPLX (67%)/ Delek Logistics (33%) • Cost: $119 million • Capacity: 80,000 Bbl/d • Length: 109 miles • Completed: September 2016 • Benefiting from increased drilling activity in the area; offers connection to Midland takeaway pipelines Caddo Pipeline • Delek Logistics (50%)/Plains Pipeline L.P. (50%) • Cost: $123 million • Capacity: 80,000 Bbl/d • Length: 80 miles • Completed: January 2017 • Provides additional logistics support to El Dorado refinery with third crude supply source • Delek US is an anchor shipper on both projects 15

Midstream: Big Spring Gathering System Gathering Helps Control Crude Oil Quality and Cost into Refineries  Getting closer to wellhead allows us to control crude quality and cost Big Spring Gathering System . Provides improvement in refining performance and cost structure  Drop down to DKL completed in Q1 2020  Approximately 200-mile gathering system,  Gathering increases access to barrels  350Kbpd throughput capacity . Creates optionality to place barrels:  >275,000 dedicated acres;  Big Spring (local refinery)  Points of origin: Howard, Borden, Martin and  Midland Midland counties  Colorado City (access other refineries)  Total terminal storage of 650K bbls;  Wink (to Gulf Coast)  Connection to Big Spring, TX terminal . Control quality and blending opportunities Delek Logistics Acquired 1Q20  Expected $30 - $32 million Annual EBITDA underpinned by MVC DK to DKL (1)  MVC 120mbbl/d for Big Spring system in addition to 50mbbl/d connection to 3rd party pipeline system  CAPEX potential of $33.8 million if requested if requested by DK, matched with MVC providing 12.5% ROR 1) Please see page 39 for a reconciliation of forecasted incremental annualized net income to forecasted EBITDA for the Big Spring Gathering System. 16

Midstream: Red River Pipeline Joint Venture Red River Pipeline JV  DKL purchased 33% interest in May 2019  Planned expansion from 150 kbpd to 235 kbpd . Approx. $128.0 million initial investment; Financed with revolver  Expected completion in second half of 2020 . DKL will contribute $20.0 million to the expansion, of which $3.5  Delek US is a major shipper on pipeline; increased million was included in initial investment in May 2019 crude oil optionality  Expected annualized adjusted EBITDA . Expected $13.5 to $15.5 million annualized adjusted EBITDA(1) pre- expansion . Increases to $20.0 to $25.0 million annualized adjusted EBITDA(1) post-expansion second half 2020 Delek US is a major shipper on pipeline; increased crude oil optionality . Increasing by 65,000 bpd to 100,000 bpd following expansion; . Incremental 24 million bbls/yr of Cushing crude oil into Longview, TX . From Longview, TX DKL access to:  Delek US refining system; Ability to reduce dependence on Midland crude oil at Tyler, El Dorado and Krotz Springs  Gulf Coast markets through Paline and other third party pipelines Longview  Increases potential WTI-Brent exposure with limited cost to the company 1) Please see page 37 for a reconciliation of forecast incremental annualized net income to forecast incremental annualized adjusted EBITDA. 17

Asset Overview: Paline Pipeline Provides access to Gulf Coast and ability to take advantage of crude differentials • Approximately 195 mile 42 kbpd crude oil pipeline – Longview, TX south to Beaumont, TX • Allows shippers ability ship Midland or Cushing crude barrels to the Gulf Coast • Increased demand for space on pipeline as crude oil differentials have widened • Increased tariff • Incentive tariff of $0.75/bbl expired on Feb. 28 • Tariff increased to FERC rate of $1.57/bbl • Expected increase in EBITDA of $900,000/month(1) 1) Please see page 36 for a reconciliation of forecasted EBITDA to forecasted net income. Based on rates prior to July 1, 2019 FERC adjustment. 18

West Texas Wholesale Business Benefiting from Permian Basin crude oil drilling activity West Texas Wholesale and Marketing Gross Margin(1) • Operates in an area around the Permian Basin; Complementary to Delek US refining/retail in region ($ in millions) • Purchases refined products from Delek US & third $30.0 parties for resale at owned and third party terminals in $25.0 west Texas • Includes ethanol blending activity $20.0 • Positioned to benefit from positive industry $15.0 dynamics: $10.0 • Drilling rig count currently shows 198 rigs operating in the Permian Basin(2) $5.0 • Improved efficiencies in the Permian Basin have $8.48 $15.48 $14.05 $28.18 $7.98 $6.93 $20.32 $27.09 $17.95 $0.0 benefitted rig production levels 2011 2012 2013 2014 2015 2016 2017 2018 2019 • Forecast for continued production growth • Current takeaway pipeline capacity is adequate • Potential for tight production/takeaway capacity in future 1) RINs gross margin benefit included in the 2013 West Texas gross margin per barrel was approximately $6.4 million, or $0.99/Bbl, 2014 gross margin included $4.6 million, or $0.75/Bbl, 2015 gross margin included $5.3 million, or $0.89/Bbl, 2016 gross margin included $6.7 million, or $1.39/bbl, 2017 gross margin included $5.6 million, or $1.11/bbl, 1Q18 gross margin included $1.1 million, or $0.81/bbl, 2Q18 gross margin included $0.8 million, or $0.71/bbl, 3Q18 gross margin included $0.3 million, or $0.29/bbl, 4Q18 gross margin included $0.3 million, or $0.27/bbl, 1Q19 gross margin included $0.3 million, or $0.27/bbl; 2Q19 included $0.3 million or $0.25/bbl; 3Q19 included $0.3 million or $0.38/bbl; 4Q19 included $0.3mm or $0.28/bbl. 19 2) Source: Baker Hughes Drilling Rig report through May 8, 2020.

Asset Overview: El Dorado Assets and Gathering Assets El Dorado Assets (1) El Dorado Assets 70,000 • Provides non-gathered crude oil to Delek US’ 60,000 El Dorado refinery and connects to Enterprise 50,000 TE Products Pipeline to move finished 40,000 products. 30,000 • Crude and light product throughput can Barrels Barrels per day 20,000 benefit from improvements at Delek US’ El 10,000 Dorado refinery. 47,906 53,461 54,960 57,366 56,555 52,071 59,362 51,927 51,992 45,728 42,918 37,716 - 2014 2015 2016 2017 2018 2019 (1) Crude Volume (bpd) Refined product (bpd) Gathering Assets 30,000 Gathering Assets • Provides access to local Arkansas, east Texas 25,000 and north Louisiana crudes to Delek US’ El 20,000 Dorado refinery. 15,000 • 600 mile crude oil gathering system, primarily 10,000 within a 60-mile radius of the El Dorado Barrels per day 5,000 refinery. 17,676 20,747 22,152 22,656 20,673 17,756 15,871 16,571 21,869 - • Crude price environment plays role in 2011 2012 2013 2014 2015 2016 2017 2018 2019 (2) production from local producers. Crude Volume (bpd) (1) During March and April 2019 El Dorado underwent a scheduled 5 year turnaround that reduced throughputs. (2) Delek US acquired majority ownership of Lion Oil in April 2011. Volumes in 2011 are based on 247 days of operations following the acquisition. 20

Asset Overview: Terminalling Terminal Count Terminalling Assets (1) 12 • Refined products terminalling services for Delek US and/or third parties • Comprised of terminals located in: 9 • Memphis and Nashville, TN; 6 • Big Spring (asphalt and light products), Tyler, Big Sandy (1) and Mt. Pleasant, TX; 3 • El Dorado and North Little Rock, AR • Duncan, OK - 2011 2012 2013 2014 2015 2016 2017 2018 2019 West Texas Wholesale Other Terminals Drop Down Terminals Primary Terminalling Asset Detail (1) Volume (MBbl/d) Number of Active Shell Number of Truck Truck Loading Location Tanks Capacity (MBbls) Loading Lanes Capacity (MBbl/d) Big Sandy, TX --- --- 3 25 Memphis, TN 12 126 3 20 Nashville, TN (2) 10 128 2 15 Tyler, TX --- --- 11 91 North Little Rock, AR --- --- 2 17 El Dorado, AR --- --- 3 35 Mount Pleasant, TX 6 155 3 10 19 13 75 97 107 122 124 159 160 Big Spring, TX (light --- --- 4 54 2011 2012 2013 2014 2015 2016 2017 2018 2019 products) (1) Big Sandy was not operating during 2011, 2012 and the majority of 2013. However, contract with Delek US has a minimum throughput requirement of 5,000 Bbl/d along with a minimum storage requirement. For reporting purposes, San Angelo and Abilene terminals are included in the west Texas wholesale business. The remaining are in terminalling. (2) Excludes approximately 10 MBbls of shell capacity that is not currently in service. 21

Going Forward: Growing Midstream Assets

Delek US: Wink to Webster Wink to Webster Pipeline JV  650-mile 36-inch diameter crude oil pipeline  Wink to Webster Pipeline LLC – Exxon, Plains, MPLX, Delek US, Rattler Midstream, Lotus Midstream  Delek US’ Investment  Total system expected completion 2021 . Delek US has 15% ownership interest in Wink to Webster  Supported by significant volume of long term Pipeline LLC commitments . Expected $340 million to $380 million net investment . Integrated with Big Spring gathering system to provide source of barrels and services to producers  Well above Delek US’ targeted minimum required midstream IRR of 15%  Secured project financing for approximately 80% of Big Spring our investment Midland . ~$69 million reimbursement in 1Q20 Wink . Results in ~$75 million equity contribution; balance to be project financed Beaumont Junction Webster/ Baytown 23

Midstream:Midstream: UtilizingUtilizing Free Free Cash Cash Flow Flow & Strong & Strong Balance Balance Sheet to Sheet Fund toGrowth Fund Growth Supports goal to generate approximately $370 million to $395 million of annualized midstream adjusted EBITDA by ’23 Supports goal to generate approximately $370 million to $395 million of annualized midstream adjusted EBITDA by ’23 Strong Adjusted EBITDA Growth Profile from Midstream Initiatives (1) ($ in millions) Delek US announced goal to achieve $370-$395 $110-$133 midstream target by 2023 $32 $30-$32 $188 $8 Delek Logistics provides platform to $3 unlock logistics value Red River excludes EBITDA generated in LTM LTM LTM EBITDA ($6)/Post Pre Gathering Springs Krotz Midstream Adj. EBITDA Big Spring Big Annualized Red JV Red River Midstream Potential projects growth 3/31/20 Exp ($8) Exp Other Assets Total (2) (2) (4) (3) (4) (2) Red River Joint Venture (2) Big Spring Gathering Krotz Springs Midstream Assets Midstream Growth Projects by •Pre Expansion: Expected $13.5 to $15.5 •$30 - $32 million EBITDA underpinned by •$30 to $34 million EBITDA / year (2) 2023: million annualized adjusted EBITDA MVC DK to DKL (2) •Other organic midstream growth projects •Post Expansion: Increases to $20.0 to $25.0 •MVC 120mbbl/d for Big Spring system in being invested in by strong sponsor DK rd million annualized adjusted EBITDA (second addition to 50mbbl/d connection to 3 •Wink to Webster Long Haul half 2020 completion) party pipeline system •Other organic growth 1) Information for illustrative purposes only to show potential based on estimated dropdown assets listed. Actual amounts will vary based on market conditions, which assets are dropped, timing of dropdowns, actual performance of the assets and Delek Logistics in the future. Expected amounts adjusted for what is captured in the LTM period. 2) Please see pages 35, 38, and 37 for a reconciliation of forecasted EBITDA or adjusted EBITDA to forecasted net income for the Krotz Springs midstream assets, Big Spring Gathering, and Red River joint venture. respectively. 3) Please see page 34 for reconciliation of Delek Logistics net income to EBITDA. 4) We are unable to provide a reconciliation of this forward-looking estimate of adjusted EBITDA because certain information needed to make a reasonable forward-looking estimate of net income is difficult to estimate and dependent on future events, which are uncertain or outside of our control, including with respect to unknown construction timing, unanticipated construction costs and other potential variables. Accordingly, a reconciliation to net income as the most comparable GAAP measure is not available without unreasonable effort. These amounts that would require unreasonable effort to quantify could be significant, such that the amount of projected GAAP net income would vary substantially from the amount of EBITDA 24 adjusted projected.

Several Visible Pathways for Growth Focused around developing Permian platform; Growing logistics asset base at sponsor Ability to Leverage Relationship with Delek US • Permian-based refining system with 207,000 bpd of Permian crude access (1) Midstream • Constructing Big Spring Gathering System in the Permian Basin Growth • Wink to Webster long haul crude oil pipelines joint venture investment Initiatives • Krotz Springs midstream assets Benefit from • High utilization rates at refineries support DKL volumes; Potential improvement in throughput capability Operations and/or flexibility at Delek US’ refineriescan be supported by DKL logistics assets Financial Flexibility provides ability to be opportunistic to develop platform • $155 million of availability at March 31, 2020 on $850 million revolving credit facility Balance Sheet • Leverage ratio was 4.15x at end of 1Q20 Supportive • Focus on organic growth, deleveraging following Red River acquisition, supporting coverage • Acquired 33% interest in Red River pipeline joint venture from Plains Pipeline, L.P. in May 2019 Acquisitions • Connects platform to Cushing, Oklahoma into Longview, Texas; increases Delek US crude flexibility • Potential growth in RIO and Caddo joint venture projects; Evaluate Paline Pipeline capacity Organic Growth • Focus on incremental improvements in existing asset base Opportunities • Delek US’ Midstream buildout provides future growth opportunities Focus on continued distribution growth Distribution • Driven by organic growth at DKL and potential increased drop down inventory at sponsor (1) Please see page 4 for additional information related to Delek US’ position in the Permian. 25

Current Valuation Below Peer EV-to-EBITDA DKL’s financial flexibility and growth initiatives of strong sponsor DK positions it for growth EV/EBITDA 12.0x 10.0x 8.0x 6.0x 4.0x 2.0x 0.0x DKL HEP MPLX PBFX PSXP PAA NS MMP ET EPD 2020 2021 20 Avg 21 Avg (1) Based on Factset as of May 14, 2020. 26

Majority of assets support Primarily traditional, stable Delek US’ strategically MLP assets with limited located inland refining commodity price exposure system Balance sheet positioned Inflation-indexed fees for to grow with strong most contracts sponsor DK Majority of all margin Agreements with Delek US generated by long term, related to capex/opex fee-based contracts with reimbursement volume minimums

Appendix

Summary of Certain Contracts(8) ` Termination Provision Minimum Tariff / Fee Refinery Initial / Maximum Term (1) Service Q120 Throughput (bpd)(2) Commitment (bpd) Current Tariff / Fee Index (10) Shutdown Force Majeure DKL Permian Gathering 99,287 120,000 $0.70 CPI-U Ten Years Crude Gathering > 120,000 $0.50 CPI-U 99,094 50,000 $0.25 CPI-U Ten Years Crude Oil Transportation > 50,000 $0.10 CPI-U Paline Pipeline N/A N/A FERC N/A N/A Crude Oil Transportation $1.64/Bbl (6) N/A N/A Lion Pipeline System (and SALA Gathering System) Five / Fifteen Years Crude Oil Transportation 55,471 46,000 (3) $1.033/Bbl (4) FERC Refined Products Five / Fifteen Years Transportation 10,427 40,000 $0.121/Bbl FERC After 3rd Five / Fifteen Years Crude Oil Gathering 33,145 14,000 $2.775/Bbl (4) FERC year, 12 East Texas Crude Logistics months notice; unless Five / Fifteen Years Crude Oil Transportation 14,160 35,000 $0.4861/Bb (5) FERC After 1st two min. years, 12 payments Five / Fifteen Years Crude Oil Storage N/A N/A $301,000 per month FERC months notice made then East Texas Marketing required cannot be terminated (7) (7) by Delek Ten Marketing - Tyler Refinery 72,840 50,000 $0.8114/Bbl CPI-U Logistics Memphis Terminal Dedicated Terminalling Five / Fifteen Years Services 10,716 10,000 $0.6075/Bbl FERC North Little Rock Terminal Dedicated Terminalling Eight / Sixteen Years Services 9,441 8,100 $0.3163/Bbl PPI-fg Eight / Sixteen Years Storage N/A N/A $68,712 per month PPI-fg Big Sandy Terminal & Pipeline Dedicated Terminalling Five / Fifteen Years Services 1,100 5,000 $0.6061/Bbl FERC Refined Products Four / Fourteen Years Transportation 1,566 5,000 $0.6061/Bbl FERC Five / Fifteen Years Storage N/A N/A $60,701 per month FERC Tyler Dedicated Terminalling Eight / Sixteen Years Services 73,330 50,000 $0.3817/Bbl PPI-fg Eight / Sixteen Years Storage N/A N/A $905,056 per month PPI-fg Eight / Sixteen Years Crude Oil Storage N/A N/A $196,319 per month PPI-fg Not applicable to this asset El Dorado Dedicated Terminalling Eight / Sixteen Years Services 9,182 22,500 $0.5454/Bbl PPI-fg Eight / Sixteen Years Storage N/A N/A $1.42 million per month PPI-fg Nine / Fifteen Years Crude Oil Offloading (9) N/A N/A $1.091/bbl light; $2.454/bbl heavy PPI-fg Big Spring Ten / fifteen Years Marketing 67,123 65,000 $0.7375/Bbl PPI-fg Ten / fifteen Years Storage N/A N/A $1.9 million per month PPI-fg Ten / fifteen Years Rail Offloading 2,466 4,500 $0.4155/Bbl PPI-fg Dedicated Terminalling Ten / fifteen Years Services 19,377 29,250 $0.6855/Bbl PPI-fg Dedicated Terminalling 1,020 to 2,380 based Ten / fifteen Years Services - Asphalt 648 on seasonality $8.621/Bbl PPI-fg Product Pipeline Ten / fifteen Years connections 16,820 27,300 $0.052/Bbl FERC Ten / fifteen Years Crude Pipeline connections 125,971 77,000 $0.052/Bbl FERC 29

Summary of Certain Contracts Footnotes (1) Maximum term assumes an extension of the commercial agreement pursuant to the terms thereof. Please note some terms began as early as Nov. 7, 2012. (2) Represents average daily throughput for the period indicated. (3) Excludes volumes gathered on the SALA Gathering System. (4) Volumes gathered on the SALA Gathering System will not be subject to an additional tariff fee for transportation on the Lion Pipeline System to the El Dorado refinery. (5) For any volumes in excess of 50,000 bpd, the throughputfee will be $0.699/Bbl. (6) Current base FERC tariff of $1.64 per barrel is in effect. On March 1, 2018 a TSA was implemented for $0.75/bbl at 30,000 bbl/d or greater for 1 year contract, which expired on Feb. 28, 2019. (7) Following the primary term, the marketing agreement automatically renews for successive 1-yr terms unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. The tariff per barrel is based on volume in each period. (8) For more detailed information regarding certain contracts, refer to documents filed with the SEC, including the Annual Reports filed on Form 10-K, Quarterly Reports filed on Form 10-Q, Current Reports on Form 8-K and 8-K/A filed on Nov. 7, 2012, Jul. 31, 2013, Aug. 1, 2013, Feb. 14, 2014, April 6, 2015 and March 26, 2018. (9) Crude oil offloading throughput agreement includes an obligated minimum quarterly throughput fee of $1.6 million for throughput of a combination of light and heavy crude. (10) The tariff/fee index can increase or decrease based on the index change pursuant to each contract. 30

Third Amended and Restated Omnibus Agreement, as amended Key Provisions • Delek US will indemnify Delek Logistics for certain liabilities, including environmental and other liabilities, relating to contributed assets. • Delek US has a ROFR if Delek Logistics sells any assets that serves Delek US' refineries or the Paline Pipeline. • GP will not receive a management fee from the Partnership; Delek Logistics will pay Delek US an annual fee for G&A services and will reimburse the GP and/or Delek US for certain expenses. • Limitations on exposure to assets contributed by Delek US relative to maintenance capital expenditures and certain expenses associated with repair/clean-up related events. • For additional detailed information regarding this agreement, please refer to documents filed with the SEC, including the Current Reports on Form 8-K filed March 26, 2018, and April 6, 2015 and the quarterly report, Form 10Q, filed August 6, 2015, as amended on November 6, 2015. 31

Summary Organizational Structure Delek US Holdings, Inc. Delek Logistics GP, LLC Public Unitholders NYSE: DK 94.6% (the General Partner) ownership interest (1) 61.4% interest Limited partner-common 2.0% interest 36.6% interest General partner interest Limited partner-common Incentive distribution rights Delek Logistics Partners, LP NYSE: DKL (the Partnership) 100% ownership interest Operating Subsidiaries 1) As of December 31, 2019, a 5.4% interest in the Delek US ownership interest in the general partner is held by three members of senior management of Delek US. The remaining ownership interest is indirectly held by Delek US. 32

DKL: Reconciliation of Cash Available for Distribution (dollars in millions, except coverage) 2013 (2) 1Q14 (2) 2Q14(2) 3Q14(2) 4Q14(2) 2014 (2) 1Q15(2) 2Q15 3Q15 4Q15 2015 (2)(3) 1Q16 2Q16 3Q16 4Q16 2016 (3) Reconciliation of Distributable Cash Flow to net cash from operating activities Net cash provided by operating activities $49.4 $14.4 $31.2 $20.1 $20.8 $86.6 $15.8 $30.8 $20.2 $1.3 $68.0 $26.4 $31.2 $29.2 $13.9 $100.7 Accretion of asset retirement obligations (0.2) (0.1) (0.1) (0.1) 0.0 (0.2) (0.1) (0.1) (0.1) (0.1) (0.3) (0.1) (0.1) (0.1) (0.1) (0.3) Deferred income taxes (0.3) 0.0 (0.1) (0.0) 0.2 0.1 (0.2) 0.2 0.0 0.0 (0.0) - - - 0.2 0.2 Gain (Loss) on asset disposals (0.2) - (0.1) - (0.0) (0.1) (0.0) 0.0 - (0.1) (0.1) 0.0 - (0.0) - 0.0 Changes in assets and liabilities 8.3 3.4 (6.0) (1.6) 3.0 (1.2) 3.3 (7.3) 3.6 20.5 20.1 (5.4) (7.1) (10.0) 7.7 (14.9) Distributions from equity method investments Maint. & Reg. Capital Expenditures (5.1) (0.8) (1.0) (0.8) (3.9) (6.5) (3.3) (3.9) (3.5) (2.7) (13.4) (0.7) (0.9) (0.7) (3.6) (5.9) Reimbursement for Capital Expenditures 0.8 - - - 1.6 1.6 1.6 1.8 2.0 0.2 5.5 0.2 0.2 0.4 2.4 3.3 Distributable Cash Flow $52.9 $17.0 $24.0 $17.7 $21.8 $80.3 $17.1 $21.4 $22.2 $19.0 $79.8 $20.4 $23.3 $18.8 $20.6 $83.0 Distribution Coverage Ratio (1) 1.35x 1.61x 2.02x 1.42x 1.67x 1.68x 1.25x 1.49x 1.47x 1.18x 1.35x 1.20x 1.29x 0.98x 1.00x 1.11x Total Distribution (1) $39.3 $10.5 $11.9 $12.4 $13.1 $47.9 $13.7 $14.4 $15.1 $16.1 $59.3 $17.1 $18.1 $19.3 $20.5 $75.0 (dollars in millions, except coverage) 1Q17 2Q17 3Q17 4Q17 (3) 2017(3) 1Q18 2Q18 3Q18 4Q18 2018 1Q19 2Q19 3Q19 4Q19 2019 1Q20 Reconciliation of Distributable Cash Flow to net cash from operating activities Net cash provided by operating activities $23.5 $23.9 $30.5 $9.8 $87.7 $23.7 $28.0 $6.0 $90.4 $148.0 $26.2 $24.1 $34.3 $45.8 $130.4 $34.8 Accretion of asset retirement obligations (0.1) (0.1) (0.1) (0.1) (0.3) (0.1) (0.1) (0.1) (0.1) (0.4) (0.1) (0.1) (0.1) (0.1) (0.4) (0.1) Deferred income taxes - (0.1) (0.0) 0.3 0.1 - - - (0.2) (0.2) - - (0.1) (0.6) (0.7) (1.3) Gain (Loss) on asset disposals (0.0) 0.0 0.0 0.0 0.0 (0.1) 0.1 (0.7) (0.2) (0.9) (0.0) 0.0 0.1 0.1 0.2 0.1 Changes in assets and liabilities (3.6) 0.9 (8.5) 14.6 3.4 3.7 6.2 28.1 (59.9) (21.9) 3.2 7.8 3.2 (14.8) (0.6) 5.6 Non-cash lease expense - - - - - (1.0) (0.4) (1.1) 2.4 (0.2) (2.9) Distributions from equity method investments 0.3 0.2 1.2 0.8 - - - 0.8 0.1 Maint. & Reg. Capital Expenditures (2.2) (2.1) (0.7) (4.4) (9.4) (0.3) (1.0) (2.4) (3.5) (7.2) (0.8) (1.0) (3.7) (2.9) (8.5) (0.9) Reimbursement for Capital Expenditures 0.9 0.5 0.4 1.7 3.5 0.4 0.3 1.3 0.9 2.9 0.7 0.7 1.2 3.2 5.8 0.0 Distributable Cash Flow $18.4 $23.0 $21.6 $21.9 $85.0 $27.3 $33.5 $32.4 $27.6 $121.5 $29.0 $31.2 $33.7 $33.0 $126.9 $35.5 Distribution Coverage Ratio (1) 0.88x 1.06x 0.97x 0.96x 0.97x 1.14x 1.34x 1.25x 1.02x 1.19x 1.06x 1.08x 1.11x 1.08x 1.08x 1.15x Total Distribution (1) $21.0 $21.8 $22.3 $22.8 $87.9 $24.0 $25.0 $26.0 $26.9 $101.9 $27.4 $28.9 $30.3 $30.6 $117.3 $30.9 1) Distribution based on actual amounts distributed during the periods; does not include LTIP accrual. Coverage is defined as cash available for distribution divided by total distribution. 2) Results in 2013, 2014 and 2015 are as reported excluding predecessor costs related to the dropdown of the tank farms and product terminals at both Tyler and El Dorado during the respective periods. 3) In 4Q17, the reimbursed capital expenditure amounts in the determination of distributable cash flow were revised to reflect the accrual of reimbursed capital expenditures from Delek US rather than the cash amounts received for reimbursed capital expenditures during the years ended December 31, 2017, 2016 and 2015. 33 Note: May not foot due to rounding and annual adjustments that occurred in year-end reporting.

DKL: Income Statement and Non-GAAP EBITDA Reconciliation 2013(1) 1Q14(1) 2Q14 3Q14 4Q14 2014 (1) 1Q15(2) 2Q15 3Q15 4Q15 2015(2) 1Q16 2Q16 3Q16 4Q16 2016 Net Revenue $907.4 $203.5 $236.3 $228.0 $173.3 $841.2 $143.5 $172.1 $165.1 $108.9 $589.7 $104.1 $111.9 $107.5 $124.7 $448.1 Cost of Sales (811.4) (172.2) (196.6) (194.1) (134.3) (697.2) (108.4) (132.5) (124.4) (71.0) (436.3) (66.8) (73.1) ($73.5) ($88.8) (302.2) Operating Expenses (excluding depreciation and amortization presented below) (25.8) (8.5) (9.5) (10.2) (9.7) (38.0) (10.6) (10.8) (11.6) (11.7) (44.8) (10.5) (8.7) ($9.3) ($8.8) (37.2) Depreciation and Amortization Contribution Margin $70.3 $22.8 $30.2 $23.7 $29.3 $106.0 $24.5 $28.8 $29.1 $26.2 $108.6 $26.8 $30.0 $24.7 $27.2 $108.7 Operating Expenses (excluding depreciation and amortization presented below) Depreciation and Amortization (10.7) (3.4) (3.5) (3.7) (3.9) (14.6) (4.0) (4.7) (4.5) (5.9) (19.2) (5.0) (4.8) ($5.4) ($5.6) (20.8) General and Administration Expense (6.3) (2.6) (2.2) (2.5) (3.3) (10.6) (3.4) (3.0) (2.7) (2.3) (11.4) (2.9) (2.7) ($2.3) ($2.3) (10.3) Gain (Loss) on Asset Disposal (0.2) - (0.1) - - (0.1) - - - (0.1) (0.1) 0.0 - ($0.0) $0.0 0.0 Operating Income $53.2 $16.8 $24.4 $17.5 $22.1 $80.8 $17.1 $21.1 $21.8 $17.9 $77.9 $19.0 $22.5 $17.0 $19.2 $77.7 Interest Expense, net (4.6) (2.0) (2.3) (2.2) (2.1) (8.7) (2.2) (2.6) (2.8) (3.0) (10.7) (3.2) (3.3) ($3.4) ($3.7) (13.6) (Loss) Income from Equity Method Invesments (0.1) (0.3) (0.1) (0.6) (0.2) (0.2) ($0.3) ($0.4) (1.2) Income Taxes (0.8) (0.1) (0.3) (0.2) 0.5 (0.1) (0.3) (0.1) (0.1) 0.6 0.2 (0.1) (0.129) ($0.1) $0.3 (0.1) Net Income $47.8 $14.7 $21.8 $15.1 $20.5 $72.0 $14.6 $18.3 $18.6 $15.3 $66.8 $15.4 $18.9 $13.2 $15.3 $62.8 EBITDA: Net Income $47.8 $14.7 $21.8 $15.1 $20.5 $72.0 $14.6 $18.3 $18.6 $15.3 $66.8 $15.4 $18.9 $13.2 $15.3 $62.8 Income Taxes 0.8 0.1 0.3 0.2 (0.5) 0.1 0.3 0.1 0.1 (0.6) (0.2) 0.1 0.1 0.13 (0.28) 0.1 Depreciation and Amortization 10.7 3.4 3.5 3.7 3.9 14.6 4.0 4.7 4.5 5.9 19.2 5.0 4.8 5.4 5.6 20.8 Amortization of customer contract intangible assets - - - - - - - - - - - - - - - - Interest Expense, net 4.6 2.0 2.3 2.2 2.1 8.7 2.2 2.6 2.8 3.0 10.7 3.2 3.3 3.4 3.7 13.6 EBITDA $63.8 $20.2 $27.9 $21.2 $26.1 $95.4 $21.1 $25.7 $26.1 $23.6 $96.5 $23.7 $27.1 $22.0 $24.4 $97.3 1Q17 2Q17 3Q17 4Q17 2017 1Q18 2Q18 3Q18 4Q18 2018 1Q19 2Q19 3Q19 4Q19 2019 1Q20 Net Revenue $129.5 $126.8 $130.6 $151.2 $538.1 $167.9 $166.3 $164.1 $159.3 $657.6 $152.5 $155.3 $137.6 $138.6 $584.0 $163.4 Cost of Sales (92.6) (85.0) ($89.1) ($106.1) (372.9) (119.0) (106.0) ($105.6) ($98.4) (429.1) ($96.3) ($93.9) ($72.6) ($73.8) (336.5) ($101.3) Operating Expenses (excluding depreciation and amortization presented below) (10.4) (10.0) (10.7) (12.3) (43.3) (12.6) (14.9) (14.5) (15.4) (57.4) (15.3) (16.5) (17.5) (22.0) (71.3) (14.0) Depreciation and Amortization (6.3) (5.8) (12.1) (6.1) (6.2) (6.1) (6.4) (24.9) (5.8) Contribution Margin $26.5 $31.8 $30.8 $32.8 $121.9 $36.3 $45.3 $37.8 $39.6 $159.1 $34.8 $38.8 $41.3 $36.4 $151.3 $42.4 Operating Expenses (excluding depreciation and amortization presented below) (0.9) (0.4) (1.3) (0.8) (0.8) (0.9) (0.3) (2.8) (0.8) Depreciation and Amortization (5.2) (5.7) (5.5) (5.5) (21.9) (6.0) (7.0) (0.5) (0.4) (13.9) (0.5) (0.5) (0.5) (0.5) (1.8) (0.5) General and Administration Expense (2.8) (2.7) (2.8) (3.6) (11.8) (3.0) (3.7) (3.1) (7.4) (17.2) (4.5) (5.3) (5.3) (5.8) (20.8) (6.1) Gain (Loss) on Asset Disposal 0.0 0.0 (0.0) (0.0) (0.0) - 0.1 (0.7) (0.2) (0.8) (0.0) 0.0 0.1 (0.1) (0.0) 0.1 Operating Income $18.5 $23.4 $22.6 $23.7 $88.1 $27.3 $34.7 $32.6 $31.1 $125.8 $29.1 $32.3 $34.7 $29.7 $125.8 $35.0 Interest Expense, net (4.1) (5.5) (7.1) (7.3) (23.9) (8.1) (10.9) (11.1) (11.2) (41.3) (11.3) (11.4) (12.5) (12.2) (47.3) (11.8) (Loss) Income from Equity Method Invesments 0.2 1.2 1.6 1.9 5.0 0.8 1.9 1.9 1.5 6.2 2.0 4.5 8.4 5.0 19.8 5.6 Other (Expense) Income - - - - - - - - - - - (0.5) - (0.1) (0.6) - Income Taxes (0.1) (0.1) (0.2) 0.6 0.2 (0.1) (0.1) (0.1) (0.2) (0.5) (0.1) (0.1) (0.1) (0.7) (1.0) (1.0) Net Income $14.6 $19.0 $16.9 $18.9 $69.4 $20.0 $25.6 $23.3 $21.3 $90.2 $19.7 $24.9 $30.5 $21.7 $96.8 $27.8 EBITDA: Net Income $14.6 $19.0 $16.9 $18.9 $69.4 $20.0 $25.6 $23.3 $21.3 $90.2 $19.7 $24.9 $30.5 $21.7 $96.8 $27.8 Income Taxes 0.1 0.1 0.2 ($0.6) (0.2) 0.1 0.1 0.1 $0.2 0.5 0.1 0.1 0.1 0.7 1.0 1.0 Depreciation and Amortization 5.2 5.7 5.5 5.5 21.9 6.0 7.0 6.7 6.3 26.0 6.6 6.6 6.6 6.9 26.7 6.3 Amortization of customer contract intangible assets - - - - - 0.6 1.8 1.8 1.8 6.0 1.8 1.8 1.8 1.8 7.2 1.8 1) Results in 2013Interest and 2014 Expense, are as net reported excluding predecessor costs related 4.1 to the 5.5 dropdown 7.1 of the tank 7.3 farms 23.9 and product 8.1 terminals 10.9 at both 11.1 Tyler and 11.2 El Dorado 41.3 during the 11.3 respective 11.4 periods. 12.5 12.2 47.3 11.8 2) Results for 1Q15EBITDA are as reported excluding predecessor costs related to$23.9 the 1Q15$30.3 dropdowns.$29.7 $31.1 $115.0 $34.7 $45.4 $43.0 $40.7 $163.9 $39.4 $44.8 $51.5 $43.3 $178.9 $48.7 Note: May not foot due to rounding. 34

Non-GAAP Reconciliation of Krotz Springs Potential Dropdown EBITDA Krotz Springs Logistics Drop Down Reconciliation of Forecasted Annualized Net Income to Forecast Incremental EBITDA ($ in millions) Forecasted Range Forecasted Incremental Net Income$ 2.9 $ 3.3 Add Forecasted Incremental Amounts for: Depreciation and amortization 15.6 17.7 Interest and financing costs, net 11.5 13.0 Forecated EBITDA$ 30.0 $ 34.0 1) Based on projected range of potential future logistics assets that could be dropped to Delek Logistics from Delek US in the future. Amounts of EBITDA, net income and timing will vary, which will affect the potential future EBITDA and associated deprecation and interest at DKL. Actual amounts will be based on timing, performance of the assets, DKL’s growth plans and valuation multiples for such assets at the time of any transaction. 35

Non-GAAP Reconciliation of Increased Paline Pipeline Tariff EBITDA Reconciliation of Forecast Incremental U.S. GAAP Net Income (Loss) to Forecast Incremental EBITDA for Paline Pipeline Tariff Increase ($ in millions) Annual Monthly Forecasted Incremental Net Income$ 10.8 $ 0.9 Add Forecasted Incremental Amounts for: Interest Expense, net$ - $ - Depreciation and amortization$ - $ - Forecasted Incremental EBITDA $ 10.8 $ 0.9 1) Based on projected potential future performance from the Paline Pipeline using 36,000 bpd and the tariff change from an incentive rate of $0.75/bbl to the FERC rate of $1.57/bbl. Amounts of EBITDA and net income will vary. Actual amounts will be based on market conditions and pipeline operations. Based on rates prior to July 1, 2019 FERC adjustment. 36

Non-GAAP Reconciliation of Red River Joint Venture Adjusted EBITDA Delek Logistics Partners, LPReconciliation of Forecasted Incremental U.S. GAAP Net Income (Loss) to Forecasted Incremental Adjusted EBITDA for the Red River Pipeline Joint Venture ($ in millions) Pre-Expansion Range Post-Expansion Range Forecasted Incremental Net Income $5.6 $7.6 $10.1 $15.1 Add Forecasted Incremental Amounts for: Interest Expense, net 6.6 6.6 7.6 7.6 Depreciation and amortization - - - - Forecasted Incremental EBITDA $12.2 $14.2 $17.7 $22.7 Adjustments: Add Forecasted incremental distributions from operations 1.3 1.3 2.3 2.3 of non-controlled entities in excess of earnings Forecasted Incremental Adjusted EBITDA $13.5 $15.5 $20.0 $25.0 1) Based on projected potential future performance from the Red River joint venture. Amounts of adjusted EBITDA and net income will vary. Actual amounts will be based on market conditions and pipeline operations. 37

Non-GAAP Reconciliations of Big Spring Gathering System Forecasted EBITDA 38

Non-GAAP Reconciliations of Trucking Forecasted EBITDA 39

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