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| 8-K - 8-K - Delek US Holdings, Inc. | dk-8kxinvestorpresentation.htm |
Investor Presentation Delek US Holdings July 2015
Safe Harbor Provision 2 Delek US Holdings (defined as “we”, “our”) and Delek Logistics Partners, LP are traded on the New York Stock Exchange in the United States under the symbols “DK” and ”DKL” respectively, and, as such, are governed by the rules and regulations of the United States Securities and Exchange Commission. These slides and any accompanying oral and written presentations contain forward-looking statements that are based upon our current expectations and involve a number of risks and uncertainties. Statements concerning current estimates, expectations and projections about our future results, performance, prospects and opportunities and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under United States securities laws. Investors are cautioned that the following important factors, among others, may affect these forward-looking statements. These factors include but are not limited to: risks and uncertainties with the respect to the quantities and costs of crude oil, the costs to acquire feedstocks and the price of the refined petroleum products we ultimately sell; losses from derivative instruments; management's ability to execute its strategy through acquisitions and transactional risks in acquisitions; our competitive position and the effects of competition; the projected growth of the industry in which we operate; changes in the scope, costs, and/or timing of capital projects; general economic and business conditions, particularly levels of spending relating to travel and tourism or conditions affecting the southeastern United States; and other risks contained in our 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 Partners undertakes any obligation to update or revise any such forward- looking statements.
Delek US Holdings Overview 3 (1) Rail supplied light crude capability consists of 25,000 bpd of light crude or 12,000 bpd heavy crude offloading that is available at a facility owned by Delek Logistics adjacent to the El Dorado refinery. In addition, 20,000 bpd light crude capability is currently available via a third party facility adjacent to the El Dorado refinery. (2) Delek Logistics Partners, LP (NYSE:DKL) began operating on Nov. 7, 2012 and, from that date, 100% of its performance has been reported as a segment of Delek US. Delek US and its affiliates own approximately 62%, including the 2.0% general partner interest, of DKL. Storage and pipeline amounts are based on total DKL assets. Crude Sourcing/Logistics Flexibility • Pipeline Access: Midland (97,000 bpd in system) Gulf Coast and Cushing • Gathered Barrels: Local barrels in Arkansas/ North Louisiana East and West Texas • Rail Capability at El Dorado Up to 45,000 BPD of light crude(1) ;Ability to offload heavy Canadian crude Synergies Created through integration: Logistics assets support operations and create growth options Refinery locations allow ability to optimize the system Ability to support retail locations enhances margins REFINING 155,000 BPD in total El Dorado, AR 80,000 BPD 9.0 complexity Tyler, TX 75,000 BPD 8.7 complexity 360 Stores Locations in 7 states TN, AL, GA, AR, KY, MS, VA RETAIL 9 Terminals Approx. 1,250 miles of pipelines 8.7 million bbls storage capacity LOGISTICS (2) Strategic crude oil supply point that allows our refining system access to domestic inland and Gulf Coast feedstock LONGVIEW CRUDE OIL HUB Mid-Continent Integrated Downstream Energy Company – Crude Gathering to Retail Locations
4 0 122 176 146 208 80 0 176 80 255 192 0 0 128 0 127 211 141 158 211 215 185 58 7 127 127 127 Alon USA Transaction On May 14, 2015, Delek completed the acquisition of approximately 33.7 million shares, or approximately 48% of the outstanding shares, of Alon USA Energy (NYSE: ALJ) (“Alon USA”) common stock from Alon Israel Oil Company, Ltd. (“Alon Israel”). Five seats on the eleven-member Alon USA board of directors, including chairman of the board DK may own up to 49.99% in the first year at its discretion Additional ownership above this threshold during the first year is subject to approval of the independent members of Alon USA’s board of directors No limitation on DK’s ownership interest of ALJ after one year Total consideration of approximately $564.5 million(1) for this acquisition consisting of: $200 million cash(2) – financed with combination of cash on hand and borrowings on existing credit facilities, $145 million unsecured 5.5% Seller Note, and 6 million DK shares Contingent consideration of 200,000 shares (if stock greater than or equal to $50/share for 30 trading days) within two years of closing. (1) Based upon a closing price of $36.59 per share of Delek US common stock on May 13, 2015. (2) Payment was funded through a combination of cash on hand and an increase in Lion Oil’s term loan credit facility from $99.0 million to $275.0 million. The interest rate is based on LIBOR or base rate plus applicable margins, subject in each case to an all-in interest rate floor of 5.5%
Refining Segment Operational Update
Approximately 75% of crude slate consist of Midland and local crude supply Increased Access to Cost Advantaged Crude 6 45.0 45.0 87.0 97.0 17.2 17.9 18.6 18.0 0 50 100 150 200 2012 2013 2014 2015-1Q In 0 0 0 b p d Midland Local Crude Throughput Capacity $(3.31) $(2.71) $(6.11) $(2.64) $(2.81) $(2.48) $(1.84) $(0.59) 2012 2013 2014 1Q15 Apr. 2015 May 2015 Jun. 2015 Jul. 2015 Steadily improved access to cost advantaged crude (Midland/local) in refining system Recently increased Midland crude access by 10 kbpd Currently Midland and local barrels below Cushing Competitive margin in the refining sector due to: Cost advantaged crude supply Serve niche markets Reducing operating expenses per barrel WTI Midland vs WTI Cushing, $/bbl (1) Increasing Access to Cost Advantage Crude 1) Differential includes contango of $0.40/bbl (2012); contango of $0.07/bbl (2013); backwardation of $0.77/bbl (2014); contango of $0.66/bbl (Q1 2015); $2.23(Apr.); $1.91 (May); $1.18(Jun); $0.46(Jul) . Source: Argus – as of June 26, 2015; NYMEX futures settle prices 2) Company reports and estimates. Data represents actual for 2014. ALJ includes Big Spring refinery at MLP subsidiary ALDW which is owned 82% by ALJ. $4.10 $4.93 $6.77 $7.41 $7.60 $7.70 $8.39 $8.66 $11.14 PSX TSO PBF VLO HFC ALJ MPC DK WNR 2014 Peer Net Refining Margin per barrel(2) Periods incl. backwardation/contango
Increased ability to process light crude oil and ULSD capacity Improved Operating Flexibility 7 Since 2012 increased light crude processing capability by 27% based on 2015 target ULSD capability expected to improve by 37% El Dorado has ability to process 80 kbpd medium or mostly light crude Light Product Yield has improved: Tyler 98% light products El Dorado 88% light products; reduced asphalt yield 122 124 140 155 52 52 60 71 2012 2013 2014 2015 Light Crude Processing DHT Tyler Total Production, bpd 42% 47% 49% 50% 52% 51% 34% 38% 38% 39% 38% 36% 19% 10% 11% 8% 7% 10% 6% 5% 3% 2% 3% 3% 79,443 71,372 71,642 71,286 43,430 78,950 - 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000 0 0 0 1 1 1 1 2011 2012 2013 2014 1Q14 1Q15 Gasoline Diesel Asphalt Petro/Other El Dorado Total Production, bpd (2) Light Crude Processing and DHT Capacity Increased (1) (In 000 bpd) 1) 2012 and 2013 volume based on actual crude throughput. 2014 and 2015 based on total capability of the system. 2) El Dorado completed a turnaround in 1Q14. Capacity 54% 56% 54% 55% 56% 59% 38% 37% 39% 39% 38% 37% 8% 7% 7% 6% 6% 4% 59,697 59,185 62,304 65,523 65,854 19,629 - 10,000 20,000 30,000 40,000 50,000 60,000 70,000 0% 20% 40% 60% 80% 100% 120% 2011 2012 2013 2014 1Q14 1Q15 Gasoline Diesel Petro/Other
Completed in March 2015; Expected annual incremental EBITDA of $75 million Tyler Refinery Expansion and FCC Reactor Economics Based on incremental 15,000 bpd of crude throughput capacity – Estimated capital cost approximately $70 million; approx. $58 million spent in total through 3/31/15 Expected product yield +15.3 kbpd – Gasoline +7.5 kbpd – Diesel/Jet +6.7 kbpd – Other +1.0 kbpd Estimated Expansion return: – Approximately $65 million annual EBITDA – Assumed Economics: • $23.00 Gulf Coast WTI ULSD 5-3-2 crack spread; $57/bbl WTI- Cushing; $0.60 CMA • Midland sourced crude at 0.50 below Cushing • $1.00/bbl change in crack spread = $5.1m in EBITDA FCC reactor replaced during turnaround 1Q2015 • Improved yields expected to generate an additional $10.0 million of annual EBITDA 8 32.7k 40.1k 26.2k 32.9k 2.1k 2.6k 2.8k 3.3k - 20.0 40.0 60.0 80.0 Pre-Expansion Post-Expansion Gasoline Diesel/Jet LPG Other 63.7k 78.9k 52.0k 52.0k 5.5k 10.5k 10.0k 0.0 20.0 40.0 60.0 80.0 Pre-Expansion Post-Expansion WTI-Cushing or Midland East Texas Midland Crude Slate 57.5k 72.5k Product Slate
Supports High Refining Utilization Refineries Serve Local Niche Markets 9 75 150 150 210 150 275 325 375 450 0 50 100 150 200 250 300 350 400 450 500 1Q2 0 13 2Q2 0 13 3Q2 0 13 4Q2 0 13 1Q2 0 14 2Q2 0 14 3Q2 0 14 4Q2 0 14 1Q 2 015 Delek Logistics Partners terminals support refining system: Tyler refinery serves a 60 mile radius El Dorado has access to local markets, as well as Little Rock and Memphis Local market netbacks higher than Gulf Coast basis Colonial Pipeline space has increased access to Southeastern market $0.00 $0.05 $0.10 $0.15 $0.20 $0.25 $0.30 $0.35 Ja n -1 3 M ar-13 M ay-1 3 Ju l- 13 Sep- 1 3 No v-1 3 Ja n -1 4 M ar-1 4 M ay-1 4 Ju l- 14 Sep- 1 4 No v-1 4 Ja n -1 5 M ar-1 5 M ay-1 5 Delek US – Monthly Colonial Pipeline Space, (000 bbls) Gasoline Price Differential – NYMEX less Gulf Coast(1) Improving Niche Markets 1) Source for gasoline price differential is Platts with NYMEX RBOB and Gulf Coast CBOB average posted prices.
Affects of Declining Crude Oil Price Environment on Refining 10 Declining crude oil price environment has ability to improve capture rate in Delek US system A $10 per barrel decline in crude oil price can increase capture rate by $0.80 per barrel (1) Lower cost of volumetric losses at refineries Residual product such as coke, butanes, propane and propylene have lower losses Asphalt prices lag crude oil price movements; improving margins as crude declines depending on wholesale/retail sales mix; El Dorado 1Q15 asphalt production: 8,082 bpd $40 $50 $60 $70 $80 $90 $100 $110 $ p e r b ar re l ( W TI ) Mid Con Asphalt WTI 1) Based on $10/bbl decline in crude price and constant residual prices. Residual prices lag crude oil price movement and as crude oil prices stabilize margins will adjust. 2) Market information for mid-continent asphalt price and WTI crude oil at Cushing, Oklahoma. Illustrative of changes in the market and may not directly equate to refinery level margin for Delek US. Delek US sales into both the retail and wholesale markets. Source: Poten & Partners – June 2015; http://www.okladot.state.ok.us/contractadmin/pdfs/binder-index.pdf Mid-Continent Asphalt Retail Price (Oklahoma/Kansas) Compared to WTI Crude Price (2)
Operating Cost per barrel 11 Focus on reducing costs in operations Total operating cost per barrel flat year over year in 1Q15 despite lower volumes at Tyler Lower volumes at Tyler during 1Q15 turnaround and expansion resulted in higher operating cost per barrel Reduction in cost enhances competitive position $4.82 $4.71 $4.63 $4.41 $4.65 $9.76 2011 2012 2013 2014 1Q14 1Q15 Tyler Operating Expense Per Barrel Sold 60,395 61,412 63,696 66,033 23,200 $3.68 $3.40 $4.06 $3.94 $5.49 $3.72 2011 2012 2013 2014 1Q14 1Q15 El Dorado Operating Expense Per Barrel Sold 76,153 73,709 74,180 58,875 79,140 $4.18 $4.00 $4.32 $4.16 $5.05 $5.09 2011 2012 2013 2014 1Q14 1Q15 Total Refining Operating Expense Per Barrel Sold 77,369 65,263 Note: Scheduled turnaround occurred in 1Q15 Note: Scheduled turnaround occurred in 1Q14
Historical and Projected Capital Spending (excluding logistics) $42.3 $36.0 $65.9 $144.3 $201.1 $14.4 $36.5 $29.1 $37.9 $26.2 $0.1 $7.6 $26.5 $35.0 $22.4 Q1, $86.9 Q2, $46.0 Q3, $42.1 Q4, $31.2 $100.0 2010A 2011A 2012A 2013A 2014A 2015E 2016E Refining Retail Other Declining Capital Needs Expected after 2014 12 $56.8mm $80.1mm $121.5mm $217.2mm Source: Company filings and estimates. Estimates subject to changes based on operations, projects completed and market conditions. 2015E does not include capital expenditures for new retail stores during that period. 2016E does not include retail store growth. All estimates subject to change. $249.7mm $206.2mm
Logistics Operational Update
Strategic Partner in Delek Logistics Partners, LP (NYSE: DKL) 14 Delek Logistics Partners , LP (NYSE:DKL) began operating on Nov. 7, 2012 and 100% of its performance is reported as a segment of Delek US beginning 4Q12. Delek US and its affiliates own approximately 62%, including the 2.0% general partner interest, of DKL. Please see the public filings of DKL for additional information and risks associated with DKL. Note: Storage and pipeline amounts based on the pipeline and transportation segment and wholesale marketing and terminalling segment. ~525 miles of crude/product transportation pipelines, includes the 195 mile crude oil pipeline from Longview to Nederland, TX ~ 600 mile crude oil gathering system in AR/North LA Rail offloading facility Pipelines Assets Storage facilities with 8.7 million barrels of active shell capacity Storage Assets Wholesale and marketing business in Texas 9 light product terminals: TX, TN,AR Wholesale/ Terminal Assets Growing logistics assets support crude sourcing and product marketing
DKL: Improving EBITDA 15 1) Amounts provided in the Nov. 1, 2012 IPO prospectus showing forecasted performance for 12 months ending Sept. 30, 2013. 2) Information provided in Delek Logistics Partners, LP (NYSE: DKL) investor presentation available at www.deleklogistics.com for Q1 2015 LTM EBITDA based on pro forma information. Bridge compared to the forecast provided in the prospectus based on difference in performance during the period as compared to projected amounts in the prospectus. Solid EBITDA performance since IPO in Nov. 2012; Increased from projected $48.9 million to LTM $99.7 million $48.9 $99.7 $0.0 $20.0 $40.0 $60.0 $80.0 $100.0 $120.0 EBITDA, $ in millions * $12.8 $14.1 $17.0 $16.4 ($13.0) ($3.7) $3.4 $3.8
DKL: Plans in Place for Future Growth 16 Paline Pipeline ■ New agreements effective January 1, 2015 until June 30, 2016 ■ Increased volume and capacity usage rate from 2014 level ■ Potential for utilization and/or capacity increase Continued Asset Development ■ Delek US continues to develop assets to support its operations ■ Potential future drop downs could include: ■ Trucking; rail cars; retail ■ Delek US’ investment in Alon USA (NYSE: ALJ) may create additional opportunities for growth Caddo Pipeline ■ DKL (50%)/Plains All American (50%) ■ Estimated total project cost: $100 million ■ Capacity: 80,000 bpd; 80 mile pipeline; Delek US expected to be an anchor shipper ■ Location: Longview, TX to Shreveport, LA ■ Expected Startup: Mid-2016 RIO Pipeline ■ Rangeland Energy (67%)/ DKL (33%) ■ Estimated total project cost: $125 million ■ Capacity: 55,000 bpd; 107 mile pipeline; Delek US expected to be an anchor shipper ■ Location: Loving County, TX to Midland, TX ■ Expected Startup: first half 2016
DKL: Potential EBITDA Growth (1) $99.7 $6.7 $3 to $4 Approx. $1 $8.3 $2.9 Pro Forma LTM 1Q2015 (1) Potential from Identified Drop Downs (2) Potential increase from Tyler Expansion (3) Annual Tariff Increase - 2014 FERC/Inflation adj Paline repricing (4) 3rd Party Acquisitions Pipeline Joint Ventures (5) Potential EBITDA, $ in millions * Caddo Pipeline DKL 50%/ Plains 50% RIO Pipeline DKL 33%/ Rangeland 67% Exp. Compl. 2016 Exp. Inv. $91.0m 17 (1) Information provided in Delek Logistics Partners, LP (NYSE: DKL) investor presentation available at www.deleklogistics.com. 1Q2015 EBITDA based on pro forma LTM information provided in that presentation. Pro forma 2015 includes amounts for drop down contribution based on daily EBITDA expected multiplied by days when the drop down assets were not included in operations of DKL according to purchase dates. Please see public filings with the Security and Exchange Commission for additional information and risks associated with DKL. Estimates based on DKL information. LTM 1Q2015 adjusted for $3.4 million of cost (professional fees $1.2m, higher cost ethanol contracts $1.2m, Tyler turnaround effect $1.0m) that occurred during the quarter. (2) Additional drop down range based on previous guidance provide by DKL. (3) Annual benefit from Delek US’ expansion at its Tyler refinery that was completed in 1Q15. Based on 10,000 barrel per day throughput. (4) Based on agreements in effect Jan. 1, 2015. Incremental benefit versus 2014. (5) Joint venture projects are expected to be completed in the first half of 2016. Expected capital investment is approximately $91 million. Estimated project multiple range based on DKL target. *Delek Logistics Partners, LP (NYSE: DKL) estimated ranges; actual results subject to market conditions, operating performance and tariff rates. • Visible Pathways for Growth Provide Potential for Continued EBTIDA Increase in Coming Quarters (1) Frank Thompson Transport Dec. 2014 Mt. Pleasant Terminal Oct. 2014 8x to 10x EBITDA Target in place and operating to support future growth
Increased Distribution with Conservative Coverage and Leverage 18 (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 page 28 for reconciliation. (3) Based on total distributions declared on April 21 and to be paid on May 14, 2015. Adjusted for $3.4m of cost in 1Q15. (professional fees $1.2m, higher cost ethanol contracts $1.2m, lower volume associated with the Tyler refinery turnaround $1.0m) (4) Leverage ratio based on LTM EBITDA as defined by credit facility covenants for respective periods. Distribution has been increased eight consecutive times since the IPO $0.375 $0.385 $0.395 $0.405 $0.415 $0.425 $0.475 $0.490 $0.510 $0.530 - 0.200 0.400 0.600 MQD (1) 1Q 2013 2Q 2013 3Q 2013 4Q 2013 1Q 2014 2Q 2014 3Q 2014 4Q 2014 1Q15 (3) Quarterly Distribution Growth to Date 1.39x 1.32x 1.38x 1.30x 1.61x 2.02x 1.42x 1.67x 1.23x 1.48x 0.50x 1.00x 1.50x 2.00x 2.50x 1Q 2013 2Q 2013 3Q 2013 4Q 2013 1Q 2014 2Q 2014 3Q 2014 4Q 2014 1Q 2015 (3) 1Q 2015 adj(3) Avg. 1.35x in 2013 Avg. 1.69 in 2014 Distributable Cash Flow Coverage Ratio (2) 1.70x 1.58x 2.28x 2.40x 3.21x 2.69x 2.55x 2.56x 3.00x 0.50x 1.50x 2.50x 3.50x 1Q 2013 2Q 2013 3Q 2013 4Q 2013 1Q 2014 2Q 2014 3Q 2014 4Q 2014 1Q 2015 Debt / LTM EBITDA Leverage Ratio (4)
19 Marginal Percentage Interest in Distributions Assumed Distribution per Limited Partner Unit if Delek Logistics Meets 15% Annual Growth Target (2) Delek Logistics GP Incentive Distribution Rights Total Quarterly Distribution Per Unit Target Amount Unitholders General Partner Minimum Quarterly Distribution below $0.37500 98.0% 2.0% First Target Distribution $0.37500 to $0.43125 98.0% 2.0% Second Target Distribution $0.43125 to $0.46875 85.0% 15.0% Third Target Distribution $0.46875 to $0.56250 75.0% 25.0% Thereafter above $0.56250 50.0% 50.0% Current Distribution $0.530 for 1Q 2015 Delek US Ownership (1): LP Units: 14,798,516 GP Units: 494,197 (1) Includes subordinated units. (2) Based on no change in number of units and assumes all units are paid distribution. Annual growth rate based on 15% from 2014 4Q distribution of $0.51 per unit ($2.04 annualized) to 2017. Delek US and affiliates own 60% of limited partner units and the 100% of the general partner units. Information for illustrative purposes only, actual amounts will be determined by Delek Logistics based on future performance. Annual Distribution (LP and GP) to Delek US based on Assumed 15% Growth Target (2) $1.50 $1.60 $1.90 $2.25 $2.59 $2.98 $- $0.5 $1.0 $1.5 $2.0 $2.5 $3.0 $3.5 MQD annualized 2013A 2014A 2015E 2016E 2017E Distribution per LP unit $28.1 $33.3 $38.3 $44.1 $1.9 $5.4 $12.7 $22.1 $- $10.0 $20.0 $30.0 $40.0 $50.0 $60.0 $70.0 2014 2015E 2016E 2017E Distribution - LP Distribution - GP +7% +19% +18% +15% +15%
DKL: Peer Comparisons (1) 20 (1) Source: Company reports; Capital IQ 6/26/15 ; NASDAQ OMX; MLPdata.com Current Yield as of 6/26/15 Distributable Cash Flow Coverage Ratio - LTM Q1 2015 Debt / LTM EBITDA Leverage Ratio Q1 2015 1.0x 1.1x 1.1x 1.2x 1.2x 1.3x 1.4x 1.4x 1.4x 1.4x 1.6x 1.6x 0.0x 0.5x 1.0x 1.5x 2.0x PAA TLLP HEP SXL WNRL PSXP PBFX MMP EPD VLP MPLX DKL 3.0x 3.0x 3.0x 3.3x 4.0x 4.1x 4.2x 4.2x 6.8x 6.9x 7.0x - 2.0 4.0 6.0 8.0 WNRL MMP DKL MPLX PAA VLP HEP EPD PSXP SXL TLLP 6.2% 6.1% 5.7% 5.0% 4.6% 4.6% 4.6% 4.4% 3.8% 2.2% 2.1% 2.1% -0.5% 1.5% 3.5% 5.5% 7.5% PAA HEP PBFX EPD TLLP WNRL DKL SXL MMP MPLX VLP PSXP
Retail Operational Update
Fuel Gallons Sold Per Store (000’s) 1,039 1,082 1,112 1,204 270 300 2011 2012 2013 2014 1Q14 1Q15 951 1,011 1,037 1,106 247 261 2011 2012 2013 2014 1Q14 1Q15 Retail Locations Create Synergies for Product Marketing 22 Expanding Market Footprint in Markets Capable of Being Supplied by El Dorado Merchandise Sales Per Store ($000’s) Tennessee 194 locations Virginia 8 locations Kentucky and Mississippi 9 locations Arkansas 13 locations Tyler Georgia 46 locations El Dorado Red border indicates region for future growth Alabama 90 locations Markets gasoline, diesel and merchandise through a network of retail fuel and convenience stores throughout the southeastern U.S. Operates 360 stores throughout seven states Ability to supply fuel gallons to stores from refining and product logistics at Delek US Currently undergoing multi-year store enhancement initiative 60% of stores re-imaged or newly constructed Targeting 10-12 large-format stores over next twelve months $45.2 $45.2 $47.6 $61.0 $5.9 $12.3 2011 2012 2013 2014 1Q14 1Q15 Contribution Margin ($ millions)
Focused on Organic Growth 23 Large Format Stores are focal point Approximately 4,800 square feet Offer customers wider product selection Prepared food service offering increases traffic Avg. approximately 4 million gallons and $2+million inside sales once market penetrated 3 year growth trajectory for market penetration 64 large format stores in portfolio as of 1Q15 11 stores built in 2014 Current store mix of reimage, truck stops, new builds New Builds 2,600,000 3,400,000 4,000,000 Year 1 Year 2 Year 3 Large Format Store Fuel Gallons Sold Projected Performance Year 1-3 (1) (1) Projected fuel gallons sold. Actual amount will vary based on individual store location and performance over time. Continued integration with refining system supports higher fuel margins 31% 69% 2013 49% 51% 2014 68% 32% 1Q15
Current Retail Valuation Comparison 24 Valuations moving higher than historical 6x-8x range 8.9x 14.1x 12.9x 7.8x 7.7x CASY CAPL CST MUSA SUN Enterprise Value (“EV”) / Frwd. EBITDA Average = 10.3x (1) Source: Capital IQ; June 15, 2015.
Financial Update
Financial Highlights $164 $151 $130 $445 $655 $439 $610 $540 2008 2009 2010 2011 2012 2013 2014 2015 LTM At March 31, 2015 Cash of $376.4 million; Debt of $674.2 million Includes $316.4 million of debt at Delek Logistics (DKL) Excluding DKL, Delek US’ net cash position was approximately $18.6 million Capital allocation focused on capital program, acquisitions and cash returned to shareholders $125 million share repurchase plan authorized in 2015; $74.7 million repurchased in 2014 Total of $59 million of dividends paid in 2014 Investing in operations for long term growth; $257 million of capital expenditures in 2014 Approaching end of large capital spending program in first half 2015 Cash Balance ($MM) Solid Financial Performance & Delivering Value to Shareholders 26 (1) Contribution margin is defined as net sales less cost of goods sold, operating expenses and other one-time expenses, excluding depreciation and amortization. (2) Delek US assumed operational control of the El Dorado refinery and related assets through the acquisition of a majority equity interest in Lion Oil on April 29, 2011. . $68 $49 $226 $602 $400 $444 $376 2009 2010 2011 2012 2013 2014 Mar '15 Dividends Declared ($ / share) Historical Contribution Margin ($MM) (1)(2) $0.15 $0.15 $0.15 $0.21 $0.40 $0.60 $0.15 $0.18 $0.39 $0.55 $0.40 $0.15 $0.15 $0.33 $0.60 $0.95 $1.00 $0.15 2009 2010 2011 2012 2013 2014 2015 YTDRegular Special $37 $0 $8 $34 $33 $75 0 10 20 30 40 50 60 70 80 2013 1Q14 2Q14 3Q14 4Q14 2014 Share Repurchases ($MM)
Going Forward
Key Retail Cities Asphalt Terminal Third-Party Terminal Alon USA Terminal Exchange Terminal Refinery Third-Party Pipelines ALON USA Alon Pipelines (idled) Oklahoma 638167_1.wor [NY0086JT] Texas California New Mexico Arizona Nevada Oregon Washington Arkansas Louisiana Midland/i l /d andi li li li li la /i l /ai ld ndd ndi li li l Odessassde assassadedeO Corpus Christi i ir s r stCo pu Ch i i i i i i i ir r tr r ts is i i is s i iCo pu ChCo pu Chr ri ti i ir r t i i Abileneilb eneA ilililililililAb eneb eneA ilililEl Pasol sE Pa ol l l l l asl sal E P oE P ol l l Bakersfieldfi lrsake e dB fi li li li lr fr fak s i li lsak i lB e e de e dB r fi lfi lr fi l Mojavejo avejjjavavoj ejo ej Long Beach L cong ea h B L g ac L cg a on Be hon e hB PhoenixiPhoen xiiiiixixiPhoenPhoeniii TucsoncsTu oncscsTu onTu on Paramountr tPa a ounr tr ta aa aP ounP ounr tr t SouthtSou httSSou hou htt Marshrsa hrrssa ha hrr IslandI ls andI llllIIsllslandandI lI lI l Nederlandlrede andllllrrlalalede ndede ndN rllrl Houstonstou onH ttssou onou onH ttH LoopLoopLLoopoop Orlalr allllrrlalalOrllrl Moriartyir rto a yiiiir rtr rti yi yio ao ari rtir rti LubbockL cubbo kL ckL ckubboubbo Big Springi irg Sp ngBi ii ii ii irrig S i gi ig S gi iB p np nBi rii iri i Wichita Fallsi i llc t sh a Fai i lli i lli i lli i llttic i a Fallsi i llc sa Fai i llhhi it li i lti i l Fort Worth rt rtFo o h rt rtrt rtF F o o ho o hrt rt rt rt Dallasll sa aD llllllllallasll sa allD llD l Duncancun anD cacaun nun nDD Albuquerquel rbuque queAllll rrlllA buque quebuque queAl rl rl EmpireirE p eiiiirriiiE p eE p eiriri Flagstaffl ffstF ag al fflll t fft ffFlags al sF ag all t fl ftl f Elk Grovel rE k ovel Gl l l rrlk vl k vl E o eE o el Grl rl G FemleylFe eyllllF l ylF yle ee elll Richmond Beachi c ch ond ea hRi Bi i i ic aci c cai R h ond Be hh ond e hR Bi i i Krotz Springs ir tz r sK o Sp ng i i i ir t rr t rz S i gs iz sS g iK o p nK o p nr t ri ir t r i Bloomfieldl fi loo e dBl fi ll i ll i ll i lffl i ll i ll i lB oo e doo e dBl fi ll fi ll fi l TulsalsTu alllllsalsalTuTulll 0 122 176 146 208 80 0 176 80 255 192 0 0 128 0 127 211 141 158 211 215 185 58 7 127 127 127 28 Alon USA Energy/Alon USA Partners Operations ■ ALJ conducts its operations through three segments: ■ Refining and Marketing: sour and heavy crude oil refineries in Big Spring, TX; Paramount, Bakersfield and Long Beach, CA and a light sweet crude oil refinery in Krotz Springs, LA – total of ~217,000 bpd of aggregate crude oil throughput capacity (1) ■ ~640 branded independent and company- owned Alon retail locations, supplied by wholesale fuels marketing business ■ Asphalt: 10 asphalt terminals located in TX, WA, CA, AZ and NV and the largest asphalt supplier in CA and second largest asphalt supplier in TX ■ Retail: largest licensee of 7-Eleven in the U.S., operating approximately 295 convenience stores ■ Alon USA Partners, LP (“ALDW”) ■ ALJ also owns 100% of the general partner and 81.6% of the limited partner interests in ALDW ■ ALDW owns the Big Spring refinery (aggregate crude oil throughput capacity of 73,000 bpd) Source: Alon USA filings / presentations. (1) California refineries did not process crude oil in 2013 and 2014 due to the high cost of crude oil relative to product yield and low asphalt demand. 217,000 bpd of capacity Big Spring 73,000 bpd 10.5 complexity Krotz Springs 74,000 bpd 8.3 complexity California 70,000 bpd 9.2 complexity Refining Delek US acquired 48% ownership in Alon USA
29 Large, Complementary Logistics, Marketing and Retail Systems Significant Organic Growth / Margin Improvement Opportunities Focus on Shareholder Returns Strong Balance Sheet Strategically Positioned Refining Platform Questions and Answers
Appendix Additional Data
Delek US Focused on Building an Integrated Business Model A core part of Delek US' strategy is to grow via prudent strategic transactions since 2001 (1) Includes logistic assets in purchase price. Purchase price includes working capital for refineries. (2) Mt. Pleasant includes $1.1 million of inventory. 2006 Abilene & San Angelo terminals $55.1 mm 2012 Nettleton Pipeline $12.3 mm 2011 Paline Pipeline $50 mm Acquisition Completed 171 retail fuel & convenience stores & related assets $157.3 mm 2005 to 2007 2011 to 2012 2013 to Current Crude Gathering 2013 Biodiesel Facility $5.3 mm 2011 Lion refinery & related pipeline & terminals $228.7 mm(1) 2005 Tyler refinery & related assets $68.1 mm(1) 2011 - 2014 Building new large format convenience stores 2013 Tyler-Big Sandy Pipeline $5.7 mm 2014 Biodiesel Facility $11.1 mm Logistics Segment Retail Segment Refinery Segment Crude Logistics Refining Product Logistics Retail 2012 Big Sandy terminal & pipeline $11.0 mm 2013 North Little Rock Product Terminal $5.0 mm 2011 SALA Gathering Lion Oil acquisition Asset In te gr at io n Increased Gathering East and West Texas 31 2014 Mt. Pleasant System $11.1 mm (2) 2014 Frank Thompson Transport $11.6 mm 2016 Completion DKL Joint Ventures Caddo Pipeline RIO Pipeline Exp. Inv.: ~$91.0 mm 2015 48% ownership in Alon USA 2015 48% ownership in Alon USA
$42.3 $36.0 $65.9 $144.3 $201.1 $173.1 $0.9 $10.5 $5.1 $7.2 $19.7 $14.4 $36.5 $29.1 $37.9 $26.2 $18.1 $0.1 $7.6 $26.5 $35.0 $22.4 $15.0 2010A 2011A 2012A 2013A 2014A 2015F Refining Logistics (Marketing) Retail Other Historical and Projected Capital Spending 32 $56.8mm $81.0mm $132.0mm $222.3mm Source: Company filings. $256.9mm $225.9mm
-$30 -$20 -$10 $0 $10 $20 $30 $40 $50 J a n -1 0 F e b -1 0 M a r- 1 0 A pr -1 0 M a y -1 0 J u n -1 0 J u l- 1 0 A u g -1 0 S e p -1 0 O c t- 1 0 No v -1 0 De c -1 0 J a n -1 1 F e b -1 1 M a r- 1 1 A pr -1 1 M a y -1 1 J u n -1 1 J u l- 1 1 A u g -1 1 S e p -1 1 O c t- 1 1 No v -1 1 De c -1 1 J a n -1 2 F e b -1 2 M a r- 1 2 A pr -1 2 M a y -1 2 J u n -1 2 J u l- 1 2 A u g -1 2 S e p -1 2 O c t- 1 2 No v -1 2 De c -1 2 J a n -1 3 F e b -1 3 M a r- 1 3 A pr -1 3 M a y -1 3 J u n -1 3 J u l- 1 3 A u g -1 3 S e p -1 3 O c t- 1 3 No v -1 3 De c -1 3 J a n -1 4 F e b -1 4 M a r- 1 4 A pr -1 4 M a y -1 4 J u n -1 4 J u l- 1 4 A u g -1 4 S e p -1 4 O c t- 1 4 No v -1 4 De c -1 4 J a n -1 5 F e b -1 5 M a r- 1 5 A pr -1 5 M a y -1 5 J u n -1 5 Brent-WTI Cushing Spread Per Barrel WTI 5-3-2 Gulf Coast Crack Spread Per Barrel LLS 5-3-2 Gulf Coast Crack Spread Per Barrel U.S. Refining Environment Trends Refined Product Margins and WTI-Linked Feedstock Favor Delek US (1) Source: Platts; 2015 data is as of June 26, 2015; quarterly averages shown.; 5-3-2 crack spread based on HSD (2) Crack Spreads: (+/-) Contango/Backwardation (1) (2) (2) 33
($14.00) ($12.00) ($10.00) ($8.00) ($6.00) ($4.00) ($2.00) $0.00 Ja n -1 1 Fe b -1 1 M ar -1 1 A p r- 11 M ay -1 1 Ju n -1 1 Ju l-1 1 A u g- 1 1 Se p -1 1 O ct-1 1 N o v- 1 1 De c- 1 1 Ja n -1 2 Fe b -1 2 M ar -1 2 A p r- 12 M ay -1 2 Ju n -1 2 Ju l-1 2 A u g- 1 2 Se p -1 2 O ct-1 2 N o v- 1 2 De c- 1 2 Ja n -1 3 Fe b -1 3 M ar -1 3 A p r- 13 M ay -1 3 Ju n -1 3 Ju l-1 3 A u g- 1 3 Se p -1 3 O ct-1 3 N o v- 1 3 De c- 1 3 Ja n -1 4 Fe b -1 4 M ar -1 4 A p r- 14 M ay -1 4 Ju n -1 4 Ju l-1 4 A u g- 1 4 Se p -1 4 O ct-1 4 N o v- 1 4 De c- 1 4 Ja n -1 5 Fe b -1 5 M ar -1 5 A p r- 15 M ay -1 5 Ju n -1 5 Ju l-1 5 WTI Midland vs. WTI Cushing Crude Pricing Access to Midland Crudes Benefits Margins ($ per barrel) 97,000 bpd of Midland crude in DK system 34 Source: Argus – as of June 26, 2015
Non-GAAP Reconciliation 35 Source: Company filings. ($ in millions) 2008 2009 2010 2011 2012 2013 2014 1Q14 1Q15 1Q15 LTM Net sales $4,723.7 $2,666.7 $3,755.6 $7,198.2 $8,726.7 $8,706.8 $8,324.3 $1,865.7 $1,150.6 $7,609.2 Cost of goods sold 4,308.1 2,394.1 3,412.9 6,429.9 7,704.4 7,880.7 7,315.2 1,643.3 1,006.1 6,678.0 Operating expenses 240.8 219.0 229.5 320.9 363.3 387.4 398.8 98.5 91.4 391.7 Impairment of goodwill 11.2 7.0 0.0 2.2 0.0 0.0 0.0 0.0 0.0 0.0 Insurance proceeds - business interruption 0.0 (64.1) (12.8) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Property damage proceeds, net 0.0 (40.3) (4.0) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Contribution margin $163.6 $151.0 $130.0 $445.2 $659.0 $438.7 $610.3 $123.9 $53.1 $539.5 Year Ended 12/31 Delek US Contribution Margin Reconciliation ($ in millions) 2012 2013 2014 1Q14 1Q15 1Q15 LTM Net cash provided by operating activities $462.9 $102.5 $319.1 $63.7 ($39.2) $216.2 Purchase of property, plant and equipment 132.0 222.3 256.8 114.3 90.7 $233.2 Free cash flow $330.9 ($119.8) $62.3 ($50.6) ($129.9) ($17.0) Year Ended 12/31 Delek US Free Cash Flow Reconciliation
Investor Relations Contact: Assi Ginzburg Keith Johnson Chief Financial Officer Vice President of Investor Relations 615-435-1452 615-435-1366