# Delek US Holdings, Inc. (DK) Informational only - not investment advice. CIK: 0001694426 SIC: 2911 Petroleum Refining SIC breadcrumb: [Manufacturing](/division/D/) > [Petroleum Refining And Related Industries](/major-group/29/) > [SIC 2911 Petroleum Refining](/industry/2911/) Latest 10-K filed: 2026-02-27 SEC page: https://www.sec.gov/edgar/browse/?CIK=1694426 Filing source: https://www.sec.gov/Archives/edgar/data/1694426/000162828026012664/dk-20251231.htm ## Selected Fundamentals | Metric | Value | Unit | FY | Filed | | --- | ---: | --- | ---: | --- | | Revenue | 10722900000 | USD | 2025 | 2026-02-27 | | Net income | -22800000 | USD | 2025 | 2026-02-27 | | Assets | 6847700000 | USD | 2025 | 2026-02-27 | ## Financials Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-02-27. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001694426.json. Derived margins, ratios, and free cash flow are computed from the extracted annual SEC facts. | Metric | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Revenue | | | | 10,233,100,000 | 9,298,200,000 | 7,301,800,000 | 10,648,200,000 | 19,801,000,000 | 16,467,200,000 | 11,852,200,000 | 10,722,900,000 | | Net income | | -153,700,000 | 288,800,000 | 340,100,000 | 310,600,000 | -611,400,000 | -128,300,000 | 257,100,000 | 19,800,000 | -560,400,000 | -22,800,000 | | Operating income | | -49,200,000 | 180,300,000 | 611,900,000 | 492,300,000 | -732,300,000 | -34,700,000 | 457,500,000 | 244,700,000 | -491,500,000 | 301,000,000 | | Diluted EPS | | -2.49 | 4.00 | 3.95 | 4.06 | -8.31 | -1.73 | 3.59 | 0.30 | -8.77 | -0.38 | | Operating cash flow | | 248,000,000 | 319,700,000 | 560,300,000 | 575,200,000 | -282,900,000 | 371,400,000 | 425,300,000 | 1,013,600,000 | -66,800,000 | 535,800,000 | | Capital expenditures | | 46,300,000 | 172,000,000 | 322,000,000 | 413,000,000 | 269,400,000 | 222,200,000 | 280,200,000 | 392,500,000 | 427,700,000 | 529,500,000 | | Dividends paid | | 37,500,000 | 44,000,000 | 80,100,000 | 86,800,000 | 69,100,000 | 0.00 | 42,800,000 | 60,300,000 | 64,200,000 | 62,000,000 | | Share buybacks | 42,200,000 | 6,000,000 | 25,000,000 | 365,300,000 | 178,100,000 | 1,900,000 | 0.00 | 64,000,000 | 0.00 | 0.00 | | | Assets | | 2,979,800,000 | 5,935,200,000 | 5,760,600,000 | 7,016,300,000 | 6,134,100,000 | 6,812,600,000 | 8,192,800,000 | 7,171,800,000 | 6,665,800,000 | 6,847,700,000 | | Stockholders' equity | | 1,182,500,000 | 1,964,200,000 | 1,808,100,000 | 1,835,300,000 | 1,116,400,000 | 1,014,000,000 | 1,069,500,000 | 959,700,000 | 575,200,000 | 547,300,000 | | Cash and cash equivalents | | 689,200,000 | 931,800,000 | 1,079,300,000 | 955,300,000 | 787,500,000 | 856,500,000 | 841,300,000 | 821,800,000 | 735,600,000 | 625,800,000 | | Free cash flow | | 201,700,000 | 147,700,000 | 238,300,000 | 162,200,000 | -552,300,000 | 149,200,000 | 145,100,000 | 621,100,000 | -494,500,000 | 6,300,000 | ### Ratios ROE and ROA use period-end equity/assets. Liabilities / equity uses total liabilities divided by stockholders' equity. Current ratio uses current assets divided by current liabilities when both are reported. | Metric | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Net margin | | | | 3.32% | 3.34% | -8.37% | -1.20% | 1.30% | 0.12% | -4.73% | -0.21% | | Operating margin | | | | 5.98% | 5.29% | -10.03% | -0.33% | 2.31% | 1.49% | -4.15% | 2.81% | | Return on equity | | -13.00% | 14.70% | 18.81% | 16.92% | -54.77% | -12.65% | 24.04% | 2.06% | -97.43% | -4.17% | | Return on assets | | -5.16% | 4.87% | 5.90% | 4.43% | -9.97% | -1.88% | 3.14% | 0.28% | -8.41% | -0.33% | | Current ratio | | 1.49 | 0.98 | 1.45 | 1.26 | 1.21 | 0.97 | 1.20 | 0.99 | 0.93 | 0.82 | ## Quarterly Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-04-29. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001694426.json. Flow metrics use discrete quarter-length periods from 10-Q/10-Q/A filings. Q4 revenue and net income are derived only when annual FY and nine-month YTD facts exist for the same fiscal year; derived Q4 values are labeled. EPS Q4 is not derived. | Quarter | End date | Revenue | Net income | Diluted EPS | Method | | --- | --- | ---: | ---: | ---: | --- | | 2022-Q2 | 2022-06-30 | | | 5.05 | reported discrete quarter | | 2022-Q3 | 2022-09-30 | | | 0.10 | reported discrete quarter | | 2023-Q1 | 2023-03-31 | | | 0.95 | reported discrete quarter | | 2023-Q2 | 2023-06-30 | 4,195,600,000 | -8,300,000 | -0.13 | reported discrete quarter | | 2023-Q3 | 2023-09-30 | 4,748,400,000 | 128,700,000 | 1.97 | reported discrete quarter | | 2023-Q4 | 2023-12-31 | 4,049,100,000 | -164,900,000 | | derived Q4 = FY annual - nine-month YTD | | 2024-Q1 | 2024-03-31 | 3,227,600,000 | -32,600,000 | -0.51 | reported discrete quarter | | 2024-Q2 | 2024-06-30 | 3,421,700,000 | -37,200,000 | -0.58 | reported discrete quarter | | 2024-Q3 | 2024-09-30 | 3,042,400,000 | -76,800,000 | -1.20 | reported discrete quarter | | 2024-Q4 | 2024-12-31 | 2,373,700,000 | -413,800,000 | | derived Q4 = FY annual - nine-month YTD | | 2025-Q1 | 2025-03-31 | 2,641,900,000 | -172,700,000 | -2.78 | reported discrete quarter | | 2025-Q2 | 2025-06-30 | 2,764,600,000 | -106,400,000 | -1.76 | reported discrete quarter | | 2025-Q3 | 2025-09-30 | 2,887,000,000 | 178,000,000 | 2.93 | reported discrete quarter | | 2025-Q4 | 2025-12-31 | 2,429,400,000 | 78,300,000 | | derived Q4 = FY annual - nine-month YTD | | 2026-Q1 | 2026-03-31 | 2,653,100,000 | -201,300,000 | -3.34 | reported discrete quarter | ## Macro Cross-References - [CPIAUCSL](/indicator/CPIAUCSL/): Consumer Price Index for All Urban Consumers: All Items in U.S. City Average - [UNRATE](/indicator/UNRATE/): Unemployment Rate - [FEDFUNDS](/indicator/FEDFUNDS/): Federal Funds Effective Rate - [CES0500000003](/indicator/CES0500000003/): Average Hourly Earnings of All Employees, Total Private - [DFEDTARU](/indicator/DFEDTARU/): Federal Funds Target Range - Upper Limit - [DFEDTARL](/indicator/DFEDTARL/): Federal Funds Target Range - Lower Limit - [DGS3MO](/indicator/DGS3MO/): Market Yield on U.S. Treasury Securities at 3-Month Constant Maturity - [DGS2](/indicator/DGS2/): Market Yield on U.S. Treasury Securities at 2-Year Constant Maturity - [DGS10](/indicator/DGS10/): Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity - [DGS30](/indicator/DGS30/): Market Yield on U.S. Treasury Securities at 30-Year Constant Maturity - [T10Y2Y](/indicator/T10Y2Y/): 10-Year Treasury Constant Maturity Minus 2-Year Treasury Constant Maturity - [CPILFESL](/indicator/CPILFESL/): Consumer Price Index for All Urban Consumers: All Items Less Food and Energy - [CPIUFDSL](/indicator/CPIUFDSL/): Consumer Price Index for All Urban Consumers: Food - [CPIENGSL](/indicator/CPIENGSL/): Consumer Price Index for All Urban Consumers: Energy - [CUSR0000SAH1](/indicator/CUSR0000SAH1/): Consumer Price Index for All Urban Consumers: Shelter - [PCEPI](/indicator/PCEPI/): Personal Consumption Expenditures: Chain-type Price Index - [PCEPILFE](/indicator/PCEPILFE/): Personal Consumption Expenditures Excluding Food and Energy: Chain-type Price Index - [PPIACO](/indicator/PPIACO/): Producer Price Index by Commodity: All Commodities - [T10YIE](/indicator/T10YIE/): 10-Year Breakeven Inflation Rate - [U6RATE](/indicator/U6RATE/): Total Unemployed, Plus All Marginally Attached Workers Plus Total Employed Part Time for Economic Reasons - [PAYEMS](/indicator/PAYEMS/): All Employees, Total Nonfarm - [CIVPART](/indicator/CIVPART/): Labor Force Participation Rate - [EMRATIO](/indicator/EMRATIO/): Employment-Population Ratio - [UNEMPLOY](/indicator/UNEMPLOY/): Unemployed - [CE16OV](/indicator/CE16OV/): Employment Level - [ICSA](/indicator/ICSA/): Initial Claims - [JTSJOL](/indicator/JTSJOL/): Job Openings: Total Nonfarm - [JTSQUR](/indicator/JTSQUR/): Quits: Total Nonfarm - [GDPC1](/indicator/GDPC1/): Real Gross Domestic Product - [A191RL1Q225SBEA](/indicator/A191RL1Q225SBEA/): Real Gross Domestic Product: Percent Change from Preceding Period - [INDPRO](/indicator/INDPRO/): Industrial Production: Total Index - [TCU](/indicator/TCU/): Capacity Utilization: Total Index - [HOUST](/indicator/HOUST/): New Privately-Owned Housing Units Started: Total Units - [PERMIT](/indicator/PERMIT/): New Privately-Owned Housing Units Authorized in Permit-Issuing Places: Total Units - [RSAFS](/indicator/RSAFS/): Advance Retail Sales: Retail Trade - [PCE](/indicator/PCE/): Personal Consumption Expenditures - [DSPIC96](/indicator/DSPIC96/): Real Disposable Personal Income - [PSAVERT](/indicator/PSAVERT/): Personal Saving Rate - [M2SL](/indicator/M2SL/): M2 - [BOPGSTB](/indicator/BOPGSTB/): U.S. International Trade in Goods and Services: Balance - [MSPUS](/indicator/MSPUS/): Median Sales Price of Houses Sold for the United States - [HSN1F](/indicator/HSN1F/): New One Family Houses Sold: United States - [RHORUSQ156N](/indicator/RHORUSQ156N/): Homeownership Rate in the United States - [TTLCONS](/indicator/TTLCONS/): Total Construction Spending: Total Construction in the United States - [RRVRUSQ156N](/indicator/RRVRUSQ156N/): Rental Vacancy Rate in the United States - [TOTALSL](/indicator/TOTALSL/): Total Consumer Credit Owned and Securitized - [REVOLSL](/indicator/REVOLSL/): Revolving Consumer Credit Owned and Securitized - [DRCCLACBS](/indicator/DRCCLACBS/): Delinquency Rate on Credit Card Loans, All Commercial Banks - [GDP](/indicator/GDP/): Gross Domestic Product - [GPDI](/indicator/GPDI/): Gross Private Domestic Investment - [GCE](/indicator/GCE/): Government Consumption Expenditures and Gross Investment - [PCEC](/indicator/PCEC/): Personal Consumption Expenditures - [NETEXP](/indicator/NETEXP/): Net Exports of Goods and Services - [GFDEBTN](/indicator/GFDEBTN/): Federal Debt: Total Public Debt - [GFDEGDQ188S](/indicator/GFDEGDQ188S/): Federal Debt: Total Public Debt as Percent of Gross Domestic Product - [FYFSD](/indicator/FYFSD/): Federal Surplus or Deficit - [FGRECPT](/indicator/FGRECPT/): Federal Government Current Receipts - [FGEXPND](/indicator/FGEXPND/): Federal Government: Current Expenditures - [MANEMP](/indicator/MANEMP/): All Employees, Manufacturing - [USCONS](/indicator/USCONS/): All Employees, Construction - [USTRADE](/indicator/USTRADE/): All Employees, Retail Trade - [USFIRE](/indicator/USFIRE/): All Employees, Financial Activities - [USGOVT](/indicator/USGOVT/): All Employees, Government - [AWHAETP](/indicator/AWHAETP/): Average Weekly Hours of All Employees, Total Private - [DGORDER](/indicator/DGORDER/): Manufacturers' New Orders: Durable Goods - [NEWORDER](/indicator/NEWORDER/): Manufacturers' New Orders: Nondefense Capital Goods Excluding Aircraft - [BUSINV](/indicator/BUSINV/): Total Business Inventories - [EXPGS](/indicator/EXPGS/): Exports of Goods and Services - [IMPGS](/indicator/IMPGS/): Imports of Goods and Services - [IR](/indicator/IR/): Import Price Index (End Use): All Commodities - [PPIFIS](/indicator/PPIFIS/): Producer Price Index by Commodity: Final Demand ## Latest quarter (10-Q) Latest 10-Q source: https://www.sec.gov/Archives/edgar/data/1694426/000162828026028274/dk-20260331.htm Extracted structurally from real Item 2 body heading to real Item 3/4 boundary. Published MD&A gate trimmed front/tail over-capture. Confidence: high Filing date: 2026-04-29 Report date: 2026-03-31 ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") is management’s analysis of our financial performance and of significant trends that may affect our future performance. The MD&A should be read in conjunction with our condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q and in the Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on February 27, 2026 (the "Annual Report on Form 10-K"). Those statements in the MD&A that are not historical in nature should be deemed forward-looking statements that are inherently uncertain. Delek US Holdings, Inc. is a registrant pursuant to the Securities Act of 1933, as amended ("Securities Act") and is listed on the New York Stock Exchange ("NYSE") under the ticker symbol "DK". Unless otherwise noted or the context requires otherwise, the terms "we," "our," "us," "Delek" and the "Company" are used in this report to refer to Delek US Holdings, Inc. and its consolidated subsidiaries for all periods presented. You should read the following discussion of our financial condition and results of operations in conjunction with our historically condensed consolidated financial statements and notes thereto. The Company announces material information to the public about the Company, its products and services and other matters through a variety of means, including filings with the SEC, press releases, public conference calls, the Company’s website (www.delekus.com), the investor relations section of its website (ir.delekus.com), the news section of its website (www.delekus.com/news), and/or social media, including its X account (@DelekUSHoldings). The Company encourages investors and others to review the information it makes public in these locations, as such information could be deemed to be material information. Please note that this list may be updated from time to time. This Quarterly Report on Form 10-Q contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of 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, statements that refer to the the acquisition of Gravity Water Intermediate Holdings LLC ("Gravity") (the "Gravity Acquisition"), including any statements regarding the expected benefits, synergies, growth opportunities, impact on liquidity and prospects, and other financial and operating benefits thereof, statements regarding the effect, impact, potential duration or other implications of, or expectations expressed with respect to, the outbreak of a pandemic and its impact on oil production and pricing, and statements regarding our efforts and plans in response to such events, the information concerning possible future results of operations, business and growth strategies, including as the same may be impacted by any ongoing military conflict, such as the armed conflicts in Ukraine and the Middle East, financing plans, expectations that regulatory developments or other matters will or will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, and the benefits and synergies to be obtained from our completed and any future acquisitions or dispositions, statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as "may," "will," "should," "could," "would," "predicts," "potential," "continue," "expects," "anticipates," "future," "intends," "plans," "believes," "estimates," "appears," "projects" and similar expressions, as well as statements in future tense, identify forward-looking statements. Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to: •volatility in our refining margins or fuel gross profit as a result of changes in the prices of crude oil, other feedstocks, and refined petroleum products; •reliability of our operating assets; •actions of our competitors and customers; •changes in, or the failure to comply with, the extensive government regulations applicable to our industry segments, including current and future restrictions on commercial and economic activities in response to future public health crises; •our ability to execute our long-term sustainability strategy and growth through acquisitions and dispositions such as the Gravity Acquisition, and joint ventures, including our ability to successfully integrate acquisitions, complete strategic transactions, safety initiatives and capital projects, realize expected synergies, cost savings and other benefits therefrom, return value to shareholders, or achieve operational efficiencies; •diminishment in value of long-lived assets may result in an impairment in the carrying value of the assets on our balance sheet and a resultant loss recognized in the statement of operations; •the impact on commercial activity and other economic effects of any widespread public health crisis, including uncertainty regarding the timing, pace and extent of economic recovery following any such crisis; •general economic and business conditions affecting the southern, southwestern, and western United States ("U.S"), particularly levels of spending related to travel and tourism; •volatility under our derivative instruments; •deterioration of creditworthiness or overall financial condition of a material counterparty (or counterparties); •unanticipated increases in cost or scope of, or significant delays in the completion of, our capital improvement safety initiative and periodic turnaround projects; •risks and uncertainties with respect to the quantities and costs of refined petroleum products supplied to our pipelines and/or held in our terminals; •operating hazards, natural disasters, weather related disruptions, casualty losses, and other matters beyond our control; •increases in our debt levels or costs; •possibility of accelerated repayment on a portion of our Inventory Intermediation Agreement obligation if the purchase price adjustment feature triggers a change on the re-pricing dates; •changes in our ability to continue to access the credit markets; •compliance, or failure to comply, with restrictive and financial covenants in our various debt agreements; •changes in our ability to pay dividends; •seasonality; •the decline in margins impacting current results and forecasts could result in impairments in certain of our long-lived or indefinite-lived assets, including 29 | Management's Discussion and Analysis goodwill, or have other financial statement impacts that cannot currently be anticipated; •earthquakes, hurricanes, tornadoes, and other weather events, which can unforeseeably affect the price or availability of electricity, natural gas, crude oil, and other feedstocks, critical supplies, refined petroleum products and ethanol; •increases in costs of compliance with, or liability for violation of, existing or future laws, regulations and other requirements; •societal, legislative, and regulatory measures to address climate change and greenhouse gases emissions ("GHG"); •our ability to execute our sustainability improvement plans, including GHG reduction targets; •acts of terrorism (including cyber-terrorism) aimed at either our facilities or other facilities; •impacts of global conflicts such as the armed conflicts in Ukraine and the Middle East; •future decisions by the Organization of Petroleum Exporting Countries ("OPEC") and the members of other leading oil producing countries (together with OPEC, “OPEC+”) regarding production and pricing and disputes between OPEC+ members regarding the same; •disruption, failure, or cybersecurity breaches affecting or targeting our information technology ("IT") systems and controls, our infrastructure, or the infrastructure of our cloud-based IT service providers; •changes in the cost or availability of transportation for feedstocks and refined products; and •other factors discussed under Item 1A. Risk Factors and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and in our other filings with the SEC. 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 future results or period trends. We can give no assurances that any of the events anticipated by any forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations and financial condition. All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to revise or update any forward-looking statements as a result of new information, future events or otherwise. 30 | Management's Discussion and Analysis Executive Summary: Management's View of Our Business and Strategic Overview Management's View of Our Business We are an integrated downstream energy business focused on petroleum refining and the transportation, storage and wholesale distribution of crude oil, intermediate and refined products as well as wastewater processing, disposal, and recycling. Business and Economic Environment Overview Our focus on safe and reliable operations is a pillar which underlines all of our business activities. We continue to identify opportunities to mitigate market risk and focus on efforts that improve our overall cost structure while not compromising operational excellence. Our disciplined approach to cost control, coupled with a focus on our enterprise optimization plan ("EOP") margin enhancements supported strong earnings before interest, taxes, depreciation and amortization, and proportional interest, taxes, depreciation and amortization of equity method investments ("EBITDA") and cash flow, while our capital deployment remained aligned with our strategic priorities. We are focused on maintaining and expanding on the successful efforts achieved in EOP since 2024 and unlocking further free cash flow improvements across all lines of our business. In 2026, we completed the Big Spring Refinery turnaround safely, on budget and on-time, allowing us to maximize operations for the summer driving season. We also executed asset purchase agreements with Delek Logistics, (collectively referred to as “the Intercompany Agreements”) which will bring refining related activities and assets back to our refining segment and create further economic independence to our Logistics business. We also continue to deliver on strong balance sheet initiatives, including entering into amended and new credit facilities for Delek and Delek Logistics in [Excerpt truncated for page length; source filing is linked above.] ## Latest 10-K MD&A Extracted structurally from real Item 7 body heading to real Item 7A/8 boundary. Published MD&A gate trimmed front/tail over-capture. Confidence: high ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS This Annual Report on Form 10-K contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of 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, statements that refer to the H2O Midstream Acquisition and the Gravity Acquisition, including any statements regarding the expected benefits, synergies, growth opportunities, impact on liquidity and prospects, and other financial and operating benefits thereof, statements regarding the effect, impact, potential duration or other implications of, or expectations expressed with respect to, the outbreak of a pandemic and its impact on oil production and pricing, and statements regarding our efforts and plans in response to such events, the information concerning possible future results of operations, business and growth strategies, including as the same may be impacted by any ongoing military conflict, such as the Russia-Ukraine War and the Israel-Hamas War, financing plans, expectations that regulatory developments or other matters will or will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, and the benefits and synergies to be obtained from our completed and any future acquisitions or dispositions, including the sale of our Retail Stores, statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as "may," "will," "should," "could," "would," "predicts," "potential," "continue," "expects," "anticipates," "future," "intends," "plans," "believes," "estimates," "appears," "projects" and similar expressions, as well as statements in future tense, identify forward-looking statements. Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to: •volatility in our refining margins or fuel gross profit as a result of changes in the prices of crude oil, other feedstocks, and refined petroleum products; •reliability of our operating assets; •actions of our competitors and customers; •changes in, or the failure to comply with, the extensive government regulations applicable to our industry segments, including current and future restrictions on commercial and economic activities in response to future public health crises; •our ability to execute our long-term sustainability strategy and growth through acquisitions and dispositions such as the sale of our Retail Stores, the Gravity Acquisition, the H2O Midstream Acquisition, and joint ventures, including our ability to successfully integrate acquisitions, complete strategic transactions, safety initiatives and capital projects, realize expected synergies, cost savings and other benefits therefrom, return value to shareholders, or achieve operational efficiencies; •diminishment in value of long-lived assets may result in an impairment in the carrying value of the assets on our balance sheet and a resultant loss recognized in the statement of operations; •the impact on commercial activity and other economic effects of any widespread public health crisis, including uncertainty regarding the timing, pace and extent of economic recovery following any such crisis; •general economic and business conditions affecting the southern, southwestern, and western United States, particularly levels of spending related to travel and tourism; •volatility under our derivative instruments; •deterioration of creditworthiness or overall financial condition of a material counterparty (or counterparties); •unanticipated increases in cost or scope of, or significant delays in the completion of, our capital improvement safety initiative and periodic turnaround projects; •risks and uncertainties with respect to the quantities and costs of refined petroleum products supplied to our pipelines and/or held in our terminals; •operating hazards, natural disasters, weather related disruptions, casualty losses, and other matters beyond our control; •increases in our debt levels or costs; •possibility of accelerated repayment on a portion of our Inventory Intermediation Agreement obligation if the purchase price adjustment feature triggers a change on the re-pricing dates; •changes in our ability to continue to access the credit markets; •compliance, or failure to comply, with restrictive and financial covenants in our various debt agreements; •changes in our ability to pay dividends; •seasonality; •the decline in margins impacting current results and forecasts could result in impairments in certain of our long-lived or indefinite-lived assets, including goodwill, or have other financial statement impacts that cannot currently be anticipated; •earthquakes, hurricanes, tornadoes, and other weather events, which can unforeseeably affect the price or availability of electricity, natural gas, crude oil, and other feedstocks, critical supplies, refined petroleum products and ethanol; •increases in costs of compliance with, or liability for violation of, existing or future laws, regulations and other requirements; •societal, legislative, and regulatory measures to address climate change and GHG; •our ability to execute our sustainability improvement plans, including GHG reduction targets; •acts of terrorism (including cyber-terrorism) aimed at either our facilities or other facilities; •impacts of global conflicts such as the Israel-Iran War, the Israel-Hamas War, and the Russia-Ukraine War; •future decisions by OPEC and OPEC+ regarding production and pricing and disputes between OPEC+ members regarding the same; •disruption, failure, or cybersecurity breaches affecting or targeting our IT systems and controls, our infrastructure, or the infrastructure of our cloud-based IT service providers; •changes in the cost or availability of transportation for feedstocks and refined products; and •other factors discussed under Item 1A. Risk Factors and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and in our other filings with the SEC. 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 53 | Management's Discussion and Analysis 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 future results or period trends. We can give no assurances that any of the events anticipated by any forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations and financial condition. All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to revise or update any forward-looking statements as a result of new information, future events or otherwise. 54 | Management's Discussion and Analysis Executive Summary: Management's View of Our Business and Strategic Overview Management's View of Our Business We are an integrated downstream energy business focused on petroleum refining and the transportation, storage and wholesale distribution of crude oil, intermediate and refined products as well as wastewater processing, disposal, and recycling. Business and Economic Environment Overview Our focus on safe and reliable operations is a pillar which underlines all of our business activities. We continue to identify opportunities to mitigate market risk and focus on efforts that improve our overall cost structure while not compromising operational excellence. During the year we continued to make progress on our "sum of the parts" efforts. Our logistics segment (or "Logistics") successfully closed the Gravity Acquisition which includes integrated full-cycle water systems in the Permian Basin, in addition to produced water gathering, and transportation assets in the Bakken, and along with the H2O Midstream Acquisition acquired in the third quarter of 2024, provide a strong opportunity for integrated crude and water services to Delek Logistics customers. These acquisitions represents another significant step in Delek Logistics' commitment of being a full suite crude, gas and water midstream services provider in the Permian Basin in addition to diversifying our logistics customer base to include more third-party customers. Also during 2025 and 2026, we entered into additional agreements with Delek Logistics which put additional midstream commercial activities in Delek Logistics and will bring refining related activities and assets back to our refining segment (or "Refining"). These transactions increased consolidated financial availability by approximately $250 million and continue to grow Delek Logistics third-party earnings while decreasing dependence on Delek. During 2025, the Refining segment provided higher margins than 2024 due to increased crack spreads and the impact of small refinery exemptions. Crack spreads were higher during 2025 than 2024 but still lower than historic highs in 2023. Our disciplined approach to cost control, coupled with a focus on our enterprise optimization plan ("EOP") margin enhancements, as well as the impact related to the small refinery exemptions granted supported earnings before interest, taxes, depreciation and amortization ("EBITDA") growth and improved cash flow, while our capital deployment remained aligned with our strategic priorities. The domestic West Texas Intermediate ("WTI") differentials compared to Brent continued to be favorable, and the WTI Midland to Cushing differential narrowed favorably compared to 2024. The increased refining margins compared to the 2024 continues to demonstrate that demand for refined products continues to be stable. We will continue to execute on our priorities of running safe and reliable operations, making further progress on our "sum of the parts" and EOP efforts, and delivering shareholder value while maintaining our financial strength and flexibility. Our refining operations continue to be impacted by requirements to comply with RFS-2. In the third quarter of 2025, we were returned 2019-2023 RINs after being granted small refinery exemptions from the U.S. Environmental Protection Agency (“EPA”) related to the 2019-2024 compliance periods. While a majority of the RINs returned were expired and had no value, the small refinery exemptions allowed us to retain certain non-expired 2023 and 2024 RINs. Additionally, the exemptions resulted in a reduction of our Consolidated Net RINs obligation related to the unsettled 2024 obligation and a reduction within cost of materials and other in 2025. The near term economic outlook still has uncertainty due to geopolitical instability and commodity market volatility. As a result, we continue to progress our business transformation focused on enterprise-wide opportunities to improve the efficiency of our cost structure. We continued to advance our strategic initiatives aimed at long-term value creation. This includes the progress made on our EOP. The EOP includes leaner costs including lower general and administrative expenses, lower operating expenses and lower interest expense. We want to reward our shareholders with a disciplined and balanced capital allocation framework. As we strengthen our relative financial position, we believe a balanced approach between shareholder returns and balance sheet improvement is appropriate. As of December 31, 2025, we returned $141.4 million of capital in 2025 to shareholders through dividends and share buybacks. Our near-term focus is centered around the following: (1) operational excellence, (2) financial strength and flexibility, (3) strategic initiatives which includes unlocking the "sum of the parts" value of our existing business while identifying growth opportunities to enhance the Company's scale and diversify revenue streams, (4) continuing our EOP efforts to enhance margin and cash flow and (5) return to investors. See further discussion in the "Strategic Objectives" section below. See further discussion on macroeconomic factors and market trends, including the impact on 2025, in the ‘Market Trends’ section below. Other 2025 Developments Acquisition of Gravity On January 2, 2025, Delek Logistics acquired 100% of the limited liability company interests in Gravity Water Intermediate Holdings LLC from Gravity Water Holdings LLC (the "Gravity Purchase Agreement") related to water disposal and recycling operations in the Permian Basin and the Bakken for total consideration of $300.8 million, subject to customary adjustments for net working capital. The purchase price was comprised of $209.3 million in cash and 2,175,209 of Delek Logistics’ common units. 55 | Management's Discussion and Analysis Inventory Intermediation Agreement Amendment On February 21, 2025, DK Trading & Supply, LLC ("DKTS") amended the inventory intermediation agreement ("Inventory Intermediation Agreement") with Citigroup Energy Inc. ("Citi") to among other things, (i) extend the term of the Inventory Intermediation Agreement from January 31, 2026 to January 31, 2027 and (ii) include a mechanism for DKTS to nominate each month whether to include volumes related to the Krotz Springs refinery for funding under the Inventory Intermediation Agreement. On December 18, 2025, DKTS amended the Inventory Intermediation Agreement to, among other things, (i) extend the term of the Inventory Intermediation Agreement from January 31, 2027 to January 31, 2028, (ii) reduce certain commitment fees, and (iii) include a mechanism for DKTS to nominate each month whether to include volumes related to the El Dorado and Big Spring refineries for funding under the Inventory Intermediation Agreement. This amendment further reduces interest expense and other associated fees while increasing our flexibility on liquidity and inventory financing options for all refineries associated with the Inventory Intermediation Agreement. Delek Logistics On May 1, 2025, we transferred the Delek Permian Gathering purchasing and blending activities to Delek Logistics (the "DPG Dropdown”). In connection with the DPG Dropdown, Delek Logistics will assume all of the rights and obligations to purchase crude oil under certain contracts associated with Delek Logistics’ existing Midland Gathering System. Total consideration included the cancellation of $58.8 million in payables owed to Delek Logistics. On May 1, 2025, we entered into a termination agreement with Delek Logistics to terminate, in its entirety, the East Texas Marketing Agreement effective as of January 1, 2026. On May 1, 2025, in connection with the DPG Dropdown, we amended and restated a throughput agreement with Delek Logistics for the El Dorado rail facility (the “Throughput Agreement”), which includes a minimum volume commitment for refined products until the termination of the Throughput Agreement, which will occur at the closing of the El Dorado Purchase (as defined below). Additionally, on May 1, 2025, in connection with the DPG Dropdown, we entered into an asset purchase agreement with Delek Logistics (the “El Dorado Purchase Agreement”), where we will purchase the related El Dorado rail facility assets from Delek Logistics for cash consideration of $25.0 million (the “El Dorado Purchase”). The El Dorado Purchase is currently set to close January 1, 2026, subject to certain closing conditions as set forth in the El Dorado Purchase Agreement. We also entered into an amended and restated Omnibus Agreement with Delek Logistics that provides for an increase in the Administrative Fee (as defined therein) which will be phased in over two years beginning July 1, 2025 and a binding obligation for both parties to enter into transition services agreements in the event of a change in control. On January 30, 2026, we entered into asset purchase agreements with Delek Logistics, (collectively referred to as “the Intercompany Agreements”), pursuant to which we agreed to acquire a Tyler refinery tank for total consideration of $19.0 million (the “Tyler Tank Purchase”) and El Dorado tank and terminal assets for total consideration of $66.0 million (the “El Dorado Terminal Purchase”). The Tyler Tank Purchase and the El Dorado Terminal Purchase are expected to close on April 1, 2026 and October 1, 2027, respectively, in each case subject to the satisfaction of customary closing conditions. Under the Intercompany Agreements, the consideration may be paid in a combination of cash and equity, with up to $20.0 million of the aggregate consideration payable through the return of Delek Logistics common units. In addition, pursuant to the Intercompany Agreements, Delek will waive Omnibus fees for an aggregate of $4.0 million during the first two quarters of 2026. These transactions with Delek Logistics will be eliminated in consolidation. Delek Logistics Debt Agreement On June 30, 2025, Delek Logistics sold $700.0 million in aggregate principal amount of 7.325% Senior Notes due 2033 (the “Delek Logistics 2033 Notes”), at par. Net proceeds were used to repay a portion of the outstanding borrowings under the Delek Logistics Revolving Facility (as defined in Note 11 of the consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K). Small Refinery Exemptions On August 22, 2025, the EPA announced its decisions on multiple outstanding small refinery exemption (SRE) petitions from refineries seeking an exemption from their Renewable Fuel Standard obligations for the 2016–2024 compliance years. As part of the exemption review, Delek was granted full and partial exemptions for multiple refineries related to obligations for the 2019-2024 calendar years. The exemptions granted resulted in Delek being returned 2019-2023 RINs used to satisfy some of our Consolidated Net RINs obligation for previous compliance periods. A majority of these RINs were expired at the point in time the EPA returned them and lacked value. In addition, the exemptions granted for 2024 relieved or partially relieved Delek of its RIN obligations for certain refineries for the 2024 compliance year, allowing the company to retain or monetize the valid RINs that would have otherwise been required for compliance. The SREs resulted in a reduction of our Consolidated Net RINs Obligation and therefore a reduction within cost of materials and other of approximately $356.1 million in 2025. Information About Our Segments Prior to July 2024, we aggregated our operating segments into three reportable segments: refining, logistics, and retail. However, in July 2024, 56 | Management's Discussion and Analysis we entered into a definitive equity purchase agreement (the "Retail Purchase Agreement") with FEMSA. Under the terms of the Retail Purchase Agreement, Delek agreed to sell, and FEMSA has agreed to purchase, 100% of the equity interests in four of Delek’s wholly-owned subsidiaries that owned and operated 249 retail fuel and convenience stores; the Retail Stores (the "Retail Transaction"). On September 30, 2024, the Retail Transaction closed. As a result of the Retail Purchase Agreement, we met the requirements of Accounting Standards Codification ("ASC") 205-20, Presentation of Financial Statements - Discontinued Operations ("ASC 205-20") and ASC 360, Property, Plant and Equipment ("ASC 360") to report the results of the Retail Stores as discontinued operations and to classify the Retail Stores as a group of discontinued operations assets. Operations that are not specifically included in the reportable segments are included in Corporate, Other and Eliminations, which consist of our corporate activities, results of certain immaterial operating segments, including our Canadian crude trading operations and intercompany eliminations. Refining Overview The refining segment processes crude oil and other feedstocks for the manufacture of transportation motor fuels, including various grades of gasoline, diesel fuel, aviation fuel, asphalt, and other petroleum-based products that are distributed through owned and third-party product terminals. The refining segment has a combined nameplate capacity of 302,000 bpd as of December 31, 2025. A high-level summary of the refinery activities is presented below: Tyler, Texas refinery (the "Tyler refinery") El Dorado, Arkansas refinery (the "El Dorado refinery") Big Spring, Texas refinery (the "Big Spring refinery") Krotz Springs, Louisiana refinery (the "Krotz Springs refinery") Total Nameplate Capacity (bpd) 75,000 80,000 73,000 74,000 Primary Products Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfur Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfur Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfur Gasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene and ammonium thiosulfate Relevant Crack Spread Benchmark Gulf Coast 5-3-2 Gulf Coast 5-3-2 (1) Gulf Coast 3-2-1 (2) Gulf Coast 2-1-1 (3) Marketing and Distribution The refining segment's petroleum-based products are marketed primarily in the south central and southwestern regions of the United States, and the refining segment also ships and sells gasoline into wholesale markets in the southern and eastern United States. In addition, we sell motor fuels through our wholesale distribution network on an unbranded basis. (1) While there is variability in the crude slate and the product output at the El Dorado refinery, we compare our per barrel refined product margin to the U.S. Gulf Coast ("Gulf Coast") 5-3-2 crack spread because we believe it to be the most closely aligned benchmark. (2) Our Big Spring refinery is capable of processing substantial volumes of sour crude oil, which has historically cost less than intermediate, and/or substantial volumes of sweet crude oil, and therefore the WTI Cushing/ West Texas Sour ("WTS") price differential, taking into account differences in production yield, is an important measure for helping us make strategic, market-respondent production decisions. (3) The Krotz Springs refinery has the capability to process substantial volumes of light sweet crude oil to produce a high percentage of refined light products. Our refining segment also owns three biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas, Cleburne, Texas, and New Albany, Mississippi. During the second quarter of 2024, we made the decision to idle the biodiesel facilities, while exploring viable and sustainable alternatives. In the fourth quarter of 2025 we entered into an agreement to sell the Cleburne, Texas facility. In addition, the refining segment includes our wholesale crude operations and our 50% interest in a joint venture that owns asphalt terminals located in the southwestern region of the U.S. 57 | Management's Discussion and Analysis Logistics Overview Our logistics segment contains a full suite of gas, crude and water systems that gathers, transports and stores crude oil and natural gas; markets, distributes, transports and stores refined products; and disposes and recycles water in select regions of the southern United States, West Texas, New Mexico and North Dakota for our refining segment and third parties. It is comprised of the consolidated balance sheet and results of operations of Delek Logistics (NYSE: DKL), where we owned a 63.3% interest at December 31, 2025. Delek Logistics was formed by Delek in 2012 to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. A portion of Delek Logistics' assets are currently integral to our refining and marketing operations. The logistics segment's gathering and processing business owns or leases capacity on approximately 390 miles of crude oil transportation pipelines, approximately 169 miles of refined product pipelines, and approximately 767-mile crude oil gathering system. Additionally, in the Delaware Basin, we have been expanding our natural gas processing capabilities by constructing a new natural gas processing plant and adding AGI and sour gas processing capabilities. This segment also includes water disposal and recycling operations, located in the Delaware Basin of New Mexico, the Midland Basin of Texas, and the Bakken Basin of North Dakota. The storage and transportation business owns or leases associated crude oil storage tanks. The logistics segment has an aggregate of approximately 11.3 million barrels of active shell capacity. It also owns and operates nine light product terminals and markets light products using third-party terminals. Logistics has strategic investments in pipeline joint ventures that provide access to pipeline capacity as well as the potential for earnings from joint venture operations. The logistics segment owns or leases approximately 161 tractors and 306 trailers used to haul primarily crude oil and other products for related and third parties. 58 | Management's Discussion and Analysis Strategic Objectives It is vitally important that our strategic objectives, especially in view of the evolutionary direction of our macroeconomic and geopolitical environment, involve a process of continuous evaluation of our business model in terms of cost structure, as well as long-term economic and operational sustainability. More consolidation in our industry is expected from increased cost pressures due in part to the regulatory environment continuing to move towards reducing carbon emissions and transitioning to renewable energy in the long-term. However, we believe we are uniquely positioned as a leader in operating and excelling in niche markets and could continue capitalizing on our niche position by being the supplier of choice in our markets. Key Objectives Certain fundamental principles are foundational to our long-term strategy and direct us as we develop our strategic objectives. With that in mind, we have identified the following overarching key objectives: I.    Operational Excellence II.    Financial Strength and Flexibility - EOP III.    Strategic Initiatives - "sum of the parts" Operational Excellence We are committed to operational excellence which includes maintaining safe, reliable, and environmentally responsible operations. It also encompasses the dedication and drive for constant improvement across our operations in reliability, safety, and efficiency. Delek prioritizes stewardship of the environment, and we focus on how to positively impact our shareholders, employees, customers, and the communities where we operate. We believe that focusing on people, processes and equipment will lead to improved utilization and yields and ultimately better employee retention and lower costs, which translates to improved returns for our shareholders. For 2025, we are focused on the following: •Prioritize safety and environmental compliance by the continued implementation of foundational best practices to increase operations ability to provide safe, compliant, and reliable operations. •Focus on operational excellence by building out our operations centric area business teams, as well as other key competency training. •Identify and execute on low-capital organic growth projects that improve yield and increase utilization. •Continue our progression of digital system implementations that will do the following: ◦improve our ability to understand all aspects of our business as well as our ability to make real-time and forward-looking operational decisions; and ◦automate processes and shift operational roles to higher value-added activities. Financial Strength and Flexibility In our industry, as with many volatile businesses, it is very important to make capital investments with accretive returns and maintain a strong balance sheet. We want to reward our shareholders and investors with a disciplined and balanced capital allocation framework, which we believe will strengthen shareholder value by, among other things, a stable dividend complemented by opportunistic share repurchases. We are also committed to lowering costs and improving the efficiency of our cost structure in all aspects of our business. For 2025, we are focused on the following: •Reward our shareholders and investors with a disciplined and balanced capital allocation framework, including opportunities to strengthen our balance sheet by reducing debt or opportunistically repurchasing shares with excess cash. •Build on the “zero-based budget” cost saving plan completed in 2024, with a comprehensive margin enhancement plan included within the EOP. The EOP initiatives are focused on improving our financial health and ability to generate free cash flow. The EOP includes leaner costs including lower general and administrative expenses, lower operating expenses specifically at our refineries and lowering interest expense. The EOP also includes margin initiatives including accretive, minimal capital projects in our refining segment and commercial improvements through market optionality, improved Delek Logistics, and product slate optimization. Strategic Initiatives For 2026, we will continue to focus on furthering our "sum of the parts" efforts, focusing on the following: •Execute on our strategic initiatives, which may include opportunities to monetize our investment in Delek Logistics. The goal being to help unlock value embedded in the Delek valuation, along with deconsolidating Delek Logistics by reducing Delek's ownership in Delek Logistics. •Identify and evaluate investment opportunities that fit our sustainability view and integrate into our current asset footprint, including strategic investments or joint ventures in renewables or carbon capture and incubator investments in new technologies. 59 | Management's Discussion and Analysis 2025 Strategic Developments The following table highlights our 2025 Strategic Developments: 2025 Key Initiatives 2025 Strategic Developments Operational Excellence Financial Strength & Flexibility Strategic Initiatives Executing Strategic Midstream Acquisition: On January 2, 2025, Delek Logistics acquired 100% of Gravity from Gravity Water Holdings LLC related to water disposal and recycling operations in the Permian Basin and the Bakken for total consideration of $300.8 million, subject to customary adjustments for net working capital. The purchase price was comprised of $209.3 million in cash and 2,175,209 of Delek Logistics’ common units. This transaction further enhances Delek Logistics' position as full service (crude, natural gas and water) provider in the Permian basin. The acquisition is synergistic to Delek Logistics' recent acquisition of H2O Midstream and supplements Delek Logistics' integrated crude and produced water gathering and disposal offering in the Midland Basin. ü Adding Flexibility to the Inventory Intermediation Agreement: On February 21, 2025, DKTS amended the Inventory Intermediation Agreement to, among other things, include a mechanism for DKTS to nominate each month whether to include volumes related to the Krotz Springs refinery for funding under the Inventory Intermediation Agreement. This amendment reduces interest expense and other associated fees while increasing our flexibility on liquidity and inventory financing options. On December 18, 2025, DKTS amended the Inventory Intermediation Agreement to, among other things, (i) extend the term of the Inventory Intermediation Agreement from January 31, 2027 to January 31, 2028, (ii) reduce certain commitment fees, and (iii) include a mechanism for DKTS to nominate each month whether to include volumes related to the El Dorado and Big Spring refinery for funding under the Inventory Intermediation Agreement. This amendment further reduces interest expense and other associated fees while increasing our flexibility on liquidity and inventory financing options for all refineries associated with the Inventory Intermediation Agreement. ü Enterprise Optimization Plan In 2024, we implemented additional cost reduction measures across the organization and announced an enterprise optimization plan ("EOP") which included initiatives focused on improving our financial health and ability to generate cash flows. In 2025, we continued to execute on the EOP, which included leaner costs including lower general and administrative expenses, lower operating expenses and lower interest expense. ü ü ü Increasing Shareholder Value by Executing Buybacks: During the year ended December 31, 2025, 3,839,968 shares of our common stock were repurchased and cancelled at the time of the transaction for a total of $79.4 million. As of December 31, 2025, there was $464.2 million of authorization remaining under Delek's aggregate stock repurchase program. ü Monetizing Our Investment in Delek Logistics: On February 24, 2025, we entered into a Common Unit Purchase Agreement with Delek Logistics (the “Common Unit Purchase Agreement”) whereby Delek Logistics may repurchase common units from time to time from us in one or more transactions for an aggregate purchase price of up to $150.0 million through December 31, 2026. During the year ended December 31, 2025, 243,075 common units were repurchased from us and cancelled at the time of the transaction for a total of $10.0 million. As of December 31, 2025, there was $140.0 million of authorization remaining under the Common Unit Repurchase Agreement. ü ü Expanding Delek Logistics' Natural Gas Processing Capability: In April 2025, Delek Logistics began commissioning its new natural gas processing plant adjacent to its plant in the Permian Basin. The new plant has a capacity of approximately 110 MMcf/d and aims to meet the rising demand for natural gas in the region. This expansion project will also increase Delek Logistics' third party revenue. Expected annual EBITDA is estimated to be approximately $40.0 million attributable to Delek Logistics. ü ü Executing Strategic Transactions with Delek Logistics: On May 1, 2025, we entered into agreements with Delek Logistics, which among other things, transfers the Delek Permian Gathering purchasing and blending activities to Delek Logistics including all of our rights and obligations to purchase crude oil under certain contracts associated with Delek Logistics’ existing Midland Gathering System and brings back the El Dorado rail facility assets to the Refining Segment on January 1, 2026. On January 30, 2026, we entered into additional asset purchase agreements with Delek Logistics, pursuant to which we agreed to reacquire a Tyler refinery tank and El Dorado tank and terminal assets. These transactions put additional midstream commercial activities in Delek Logistics and bring refining related activities and assets back to the Refining Segment. Additionally, these transactions increase consolidated financial availability by approximately $250 million. ü ü Extending Long Term Debt Maturities: On June 30, 2025, Delek Logistics and its wholly owned subsidiary Delek Logistics Finance Corp. (“Finance Corp.” and together with Delek Logistics, the “Co-issuers”), sold $700.0 million in aggregate principal amount of the Co-issuers 7.325% Senior Notes due 2033, at par. Net proceeds were used to repay a portion of the outstanding borrowings under the Delek Logistics Revolving Facility providing Delek Logistics with $1.1 billion of availability on the facility as of June 30, 2025. ü 60 | Management's Discussion and Analysis Significant Known Uncertainties Impacting Delek Aside from the market trends and the uncertainties inherent to those market drivers many of which are referenced in the 'Executive Summary' above and which are discussed at length in the 'Market Trends' section below, we have also identified certain uncertainties that we believe to be sufficiently significant to our financial results in the near term as to warrant additional discussion. We have included supplemental discussion of those uncertainties, and our efforts for mitigating them, below. However, note that this discussion is to bring additional attention to areas that have been of particular interest to management but should not be considered comprehensive of all known trends and uncertainties which may be relevant. Instead, in the context of all known trends or uncertainties that have had, or that are reasonably likely to have, a material favorable or unfavorable effect on financial results, they should be considered part of the larger discussion on market trends and uncertainties throughout our management's discussion and analysis. Regulatory Volatility Delek is an obligated party under the RFS, which requires us to obtain RINs to satisfy our annual Renewable Volume Obligation (“RVO”). While we are able to obtain a portion of the RINs required for compliance by blending renewable fuels manufactured by third parties, we must also purchase RINs on the open market in order to comply with the quantity of renewable fuels we are required to blend under the RFS. The price and number of RINs an obligated party must acquire are impacted by government regulation requiring such credits, and also may be impacted by small refiner exemptions (“SREs”) granted by the EPA. In past years, the price of RINs has been highly volatile and the EPA’s decisions on SRE hardship petitions have been unduly delayed. Increasing RINs prices, inconsistent administration of the RFS by the EPA, and Delek’s market position has prevented us from passing through compliance costs of the program in the past and will likely continue in the future. While we cannot predict the future prices of RINs, the costs to obtain the necessary number of RINs could be material. Our future operating results are significantly dependent on the EPAs granting of SREs on a timely basis. If we are unable to pass the costs of compliance with the RFS on to our customers, if sufficient RINs are unavailable for purchase, if we have to pay a significantly higher price for RINs or if we are otherwise unable to meet the RFS mandates, our refinery operations, financial condition and results of operations could be adversely affected. In the past, we have received SREs under the RFS program for certain of our refineries. In August 2025, the EPA granted full and partial exemptions for certain of our refineries related to obligations for the 2019-2024 calendar years. We were able to use some of these RINs to satisfy our obligation for previous compliance periods. However, because RINs are valid for a one-year period, a majority of the refunded RINs had expired and therefore cannot be used or sold for value to offset future compliance obligations. The relief received also was not sufficient to offset our 2025 compliance obligation and thus Delek’s refineries will need to seek relief from the EPA for the hardship imposed by the RFS for the 2025 compliance year. Uncertainty remains regarding the impact that proposed EPA rules, or future revisions to proposed rules, may have on RINs prices, which impact the determination of the fair value of our Net RINs Obligation, as well as the fair value of forward RIN commitment contracts. Additionally, while our current Net RINs Obligation reflects current RINs market prices as of December 31, 2025, the financial statement impact, including both the income statement and net cash impact of future changes to enacted Renewable Volume Obligation rates, is not determinable because of the complexity of the Net RINs Obligation and related transactions, where such financial statement impact is dependent upon the following: (1) the composition of the specific Net RINs Obligation (in terms of the vintages of RINs we currently own versus the waived RINs Obligation) and the related market prices at the date each volumetric requirement change is enacted; (2) the composition of our RINs forward commitment contracts that may be settled or positions closed as a result of any enacted change and the related gains or losses; (3) the settlement requirements of related RINs product financing arrangements; and (4) the quantity of and dates at which excess RINs can be sold and the sales price (see also Note 12, Note 13 and Note 19 as well as our related accounting policies related to RINs included in Note 2 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K). Enacted regulatory changes could impact our financial results in ways that we cannot currently anticipate. Delek's Response to Significant Uncertainties Associated with Regulatory Volatility As discussed above, RFS activities and Renewable Volume Obligation requirements, and their impact on RIN prices, represent a significant risk which has, and could continue to, materially impact our financial results in ways that are currently uncertain. Our efforts to mitigate this risk include the following: •Actively monitoring EPA rule-making and RFS actions regarding volumetric requirements, remittance due dates, and deferral opportunities in order to make decisions about RINs inventory; •Proactively monitoring our Net RINs Obligation position (inclusive of our RINs inventory portfolio), by vintage and RIN category, in order to make decisions about the purchase and sale of RINs, based on both a current and forward basis, and considering the risk of floating versus fixed pricing; and •Incorporating into our strategic priorities activities designed to enhance incremental crack spread capture so that the impact of high RIN prices or RINs price volatility is diminished. While there continues to be risk around the fair value of the RINs Obligation that we incur and the RINs cost we recognize in our results of operations, we believe that our risk management activities around RINs are comprehensive. That said, because the RINs market is subject to factors outside of our control, there will continue to be risk that RINs cost could adversely affect our financial results. See additional discussion of the effect of RINs prices and volatility on our refining margins in the "Market Trends" section below. 61 | Management's Discussion and Analysis Market Trends Our results of operations are significantly affected by fluctuations in the prices of certain commodities, including, but not limited to, crude oil, gasoline, distillate fuel, biofuels, natural gas, and electricity, among others. Historically, the impact of commodity price volatility on our refining margins (as defined in our "Non-GAAP Measures" in MD&A Item 7), specifically as it relates to the price of crude oil as compared to the price of refined products and timing differences in the movements of those prices (subject to our inventory costing methodology), as well as location differentials, may be favorable or unfavorable compared to peers. Additionally, our refining margin profitability is impacted by regulatory factors, including the cost of RINs. We have positioned the Company to continue to run safely, reliably, and environmentally responsibly while leveraging our Delek Logistics business. Crack spreads were higher in 2025 than 2024, but below historically high crack spreads in 2023. Many uncertainties remain in 2026 with respect to the global supply and demand of the crude oil and refined products markets and it is difficult to predict the ultimate economic impacts this may have on our operations. We expect refining capacity rationalization to lower refined products inventory and crude oil demand to continue to rise. These factors will help absorb the recent additions in global supply and balance the market over the next 6 to 12 months. However, U.S. policy changes and escalating conflicts in the Middle East, Europe, and South America could potentially result in supply disruptions or further volatility in crude oil and refined products prices. See below for further discussion on how certain key market trends impact our operating results. Crude Prices WTI crude oil represents the largest component of our crude slate at all of our refineries and can be sourced through our gathering channels or optimization efforts from Midland, Texas, Cushing, Oklahoma, or other locations. We manage our supply chain risk to ensure that we have the barrels to meet our crude slate consumption plan for each month through gathering supply contracts and throughput agreements on various strategic pipelines, some of which include those where we hold equity method investments. We manage market price risk on crude oil through financial derivative hedges, in accordance with our risk management strategies. The chart below illustrates the average quarterly price of WTI Midland and WTI Cushing over the past three years. Crude Pricing Differentials Historically, domestic refiners have benefited from the discount for WTI Cushing compared to Brent, a global benchmark crude. This generally leads to higher margins in our refineries, as refined product prices are influenced by Brent crude prices and the majority of our crude supply is WTI-linked. Because of our positioning in the Permian basin, including our access to significant sources of WTI Midland crude through our gathering system, we are even further benefited by discounts for WTI Midland/WTI Cushing differentials. When these discounts shrink or become premiums, our reliance on WTI-linked crude pricing, and specifically WTI Midland crude, can negatively impact our refining margins. Conversely, as these price discounts widen, so does our competitive advantage, created specifically by our access to WTI Midland crude sourced through our gathering systems. The chart below illustrates the key differentials impacting our refining operations, including WTI Cushing to Brent, WTI Midland to WTI Cushing, and LLS to WTI Cushing over the past three years. 62 | Management's Discussion and Analysis Refined Product Prices We are impacted by refined product prices in two ways: (1) in terms of the prices we are able to sell our refined product for in our refining segment, and (2) in terms of the cost to acquire the refined products to meet refining production shortfalls (e.g., when we have outages), or to acquire refined fuel products we sell to our wholesale customers in our logistics segment. These prices largely depend on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Our refineries produce the following products: Tyler Refinery El Dorado Refinery Big Spring Refinery Krotz Springs Refinery Primary Products Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke, and sulfur Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt, and sulfur Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics, and sulfur Gasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene, and ammonium thiosulfate 63 | Management's Discussion and Analysis The charts below illustrate the quarterly average prices of CBOB, HSD and ULSD over the past three years. Crack Spreads Crack spreads are used as benchmarks for predicting and evaluating a refinery's product margins by measuring the difference between the market price of feedstocks/crude oil and the resultant refined products. Generally, a crack spread represents the approximate refining margin resulting from processing one barrel of crude oil into its outputs, generally gasoline and diesel fuel. The table below reflects the quarterly average Gulf Coast 5-3-2 ULSD, 3-2-1 ULSD and 2-1-1 HSD/LLS crack spreads for each of the quarterly periods over the past three years. 64 | Management's Discussion and Analysis RIN Volatility Environmental regulations and the political environment continue to affect our refining margins in the form of volatility in the price of RINs. We enter into future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs of our RINs Obligation. On a consolidated basis, we work to balance our RINs Obligation in order to minimize the effect of RINs prices on our results. While we obtain RINs in our refining and logistics segments through our ethanol blending, our refining segment still must purchase additional RINs to satisfy its obligations. Prior to the idling of the biodiesel facilities in 2024, we obtained RINs through biodiesel blending and generated RINs through biodiesel production. Additionally, our ability to obtain RINs through blending is limited by our refined product slate, blending capabilities and market constraints. The cost to purchase these additional RINs is a significant cash outflow for our business. Increases in the market prices of RINs generally adversely affect our results of operations through changes in fair value to our existing RINs Obligation, to the extent we do not have offsetting RINs inventory on hand or effective economic hedges through net forward purchase commitments. RINs prices are highly sensitive to regulatory and political influence and conditions, and therefore often do not correlate to movements in crude oil prices, refined product prices, or crack spreads. Because of the volatility in RINs prices, it is not possible to predict future RINs cost with certainty, and movements in RINs prices can have significant and unanticipated adverse effects on our refining margins that are outside of our control. The chart below illustrates the volatility in RINs over the past three years. 65 | Management's Discussion and Analysis Energy Costs Energy costs are a significant element of our refining segment's earnings before interest, taxes, depreciation, and amortization ("Refining EBITDA") and can significantly impact our ability to capture crack spreads, with natural gas representing the largest component. Natural gas prices are driven by supply-side factors such as the amount of natural gas production, level of natural gas in storage and import and export activity, while demand-side factors include variability of weather, economic growth and the availability and price of other fuels. Refiners and other large-volume fuel consumers may be more or less susceptible to volatility in natural gas prices depending on their consumption levels as well as their capabilities to switch to more economical sources of fuel/energy. Additionally, geographic location of facilities makes consumers vulnerable to price differentials of natural gas available at different supply hubs. Within Delek’s geographic footprint, we source the majority of our natural gas from the Gulf Coast, and secondarily from the Permian Basin, coinciding with the physical locations of our refineries. We manage our risk around natural gas prices by entering into variable and fixed-price supply contracts in both the Gulf and Permian Basin or by entering into derivative hedges based on forecasted consumption and forward curve prices, as appropriate, in accordance with our risk policy. The charts below illustrate the quarterly average prices of Waha (Permian Basin) and Henry Hub (Gulf Coast) over the past three years. Non-GAAP Measures Our management uses certain non-Generally Accepted Accounting Principles (“non-GAAP”) operational measures to evaluate our operating segment performance and non-GAAP financial measures to evaluate past performance and prospects for the future to supplement our GAAP financial information presented in accordance with U.S. GAAP. These financial and operational non-GAAP measures are important factors in assessing our operating results and profitability and include: •EBITDA - calculated as net income (loss) attributable to Delek adjusted to add back interest expense, income tax expense, depreciation, amortization and proportional interest, taxes, depreciation and amortization of equity method investments; and •Refining margin - calculated as gross margin (which we define as sales minus cost of sales) adjusted for operating expenses and depreciation and amortization included in cost of sales. We believe these non-GAAP operational and financial measures are useful to investors, lenders, ratings agencies and analysts to assess our ongoing performance because, when reconciled to their most comparable GAAP financial measure, they provide improved comparability between periods through the exclusion of certain items that we believe are not indicative of our core operating performance and they may obscure our underlying results and trends. Non-GAAP measures have important limitations as analytical tools because they exclude some, but not all, items that affect net earnings and operating income. These measures should not be considered substitutes for their most directly comparable U.S. GAAP financial measures. 66 | Management's Discussion and Analysis Non-GAAP Reconciliations The following table provides a reconciliation of EBITDA attributable to Delek to the most directly comparable U.S. GAAP measure, net (loss) income attributable to Delek: Year Ended December 31, 2025 2024 2023 Reported net (loss) income attributable to Delek US $ (22.8) $ (560.4) $ 19.8  Proportional interest, taxes, depreciation and amortization of equity-method investments 29.0  28.1  26.7  Interest expense, net 345.3  313.1  318.2  Income tax (benefit) expense (7.4) (79.2) 5.1  Depreciation and amortization 397.8  383.5  351.6  EBITDA attributable to Delek $ 741.9  $ 85.1  $ 721.4  The following table provides a reconciliation of refining margin to the most directly comparable U.S. GAAP measure, gross margin: Reconciliation of refining margin to gross margin (in millions) Refining Segment Year Ended December 31, 2025 2024 2023 Total revenues $ 10,551.3  $ 11,783.0  $ 16,406.9  Cost of sales 10,042.0  12,009.5  16,095.7  Gross margin $ 509.3  $ (226.5) 311.2  Add back (items included in cost of sales): Operating expenses (excluding depreciation and amortization) 614.6  596.6  619.2  Depreciation and amortization 270.0  265.5  234.2  Refining margin $ 1,393.9  $ 635.6  $ 1,164.6  67 | Management's Discussion and Analysis Summary Financial and Other Information The following table provides summary financial data for Delek (in millions): Summary Statement of Operations Data (1) Year Ended December 31, 2025 2024 2023 Net revenues $ 10,722.9  $ 11,852.2  $ 16,467.2  Cost of sales: Cost of materials and other 8,873.6  10,781.8  14,825.3  Operating expenses (excluding depreciation and amortization presented below) 862.9  763.8  770.6  Depreciation and amortization 374.3  349.7  322.8  Total cost of sales 10,110.8  11,895.3  15,918.7  Insurance proceeds (0.1) (20.6) (20.3) Operating expenses related to wholesale business (excluding depreciation and amortization presented below) 9.0  3.4  4.4  General and administrative expenses 269.5  252.8  272.0  Depreciation and amortization 23.5  24.8  16.7  Asset impairment 17.7  243.5  37.9  Other operating income, net (8.5) (55.5) (6.9) Total operating costs and expenses 10,421.9  12,343.7  16,222.5  Operating income (loss) 301.0  (491.5) 244.7  Interest expense, net 345.3  313.0  318.0  Income from equity method investments (89.5) (92.2) (86.2) Other expense (income), net 6.3  (6.3) (3.7) Total non-operating expenses, net 262.1  214.5  228.1  Income (loss) from continuing operations before income tax expense (benefit) 38.9  (706.0) 16.6  Income tax benefit (6.8) (107.9) (3.0) Income (loss) from continuing operations, net of tax 45.7  (598.1) 19.6  Discontinued operations: (Loss) income from discontinued operations, including gain on sale of discontinued operations (3.0) 105.9  35.2  Income tax (benefit) expense (0.6) 28.7  8.1  (Loss) income from discontinued operations, net of tax (2.4) 77.2  27.1  Net income (loss) 43.3  (520.9) 46.7  Net income attributed to non-controlling interests 66.1  39.5  26.9  Net (loss) income attributable to Delek $ (22.8) $ (560.4) $ 19.8  (1) This information is presented at a summary level for your reference. See the Consolidated Statements of Income included in item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for more detail regarding our results of operations and net income per share. We report operating results in two reportable segments: •Refining •Logistics Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on the segment EBITDA.     68 | Management's Discussion and Analysis Results of Operations Consolidated Results of Operations — Comparison of the Year Ended December 31, 2025 versus the Year Ended December 31, 2024 Net Income (Loss) 2025 vs. 2024 Consolidated net income for the year ended December 31, 2025 was $43.3 million compared to a net loss of $520.9 million for the year ended December 31, 2024. Consolidated net loss attributable to Delek for the year ended December 31, 2025 was $22.8 million, or $(0.38) per basic share, compared to a loss of $560.4 million, or $(8.77) per basic share, for the year ended December 31, 2024. Explanations for significant drivers impacting net income (loss) as compared to the comparable period of the prior year are discussed in the sections below. Net Revenues 2025 vs. 2024 We generated net revenues of $10,722.9 million and $11,852.2 million during the years ended December 31, 2025 and 2024, respectively, a decrease of $1,129.3 million, or 9.5%. The decrease in net revenues was primarily due to the following: •in our refining segment, decreases in the average price of U.S. Gulf Coast gasoline of 10.3% and ULSD of 6.4%; and •in our logistics segment, decreased revenue of $5.6 million in our West Texas marketing operations. These decreases were partially offset by the following: •increased sales volumes (including purchased products) in our refining segment; •an increase in the average price of U.S. Gulf Coast HSD of 1.0%; and •incremental revenue associated with the H2O Midstream Acquisition and Gravity Acquisition of $41.0 million and $90.1 million, respectively. Total Operating Costs and Expenses Cost of Materials and Other 2025 vs. 2024 Cost of materials and other was $8,873.6 million for the year ended December 31, 2025, compared to $10,781.8 million for the year ended December 31, 2024, a decrease of $1,908.2 million, or 17.7%. The net decrease in cost of materials and other primarily related to the following: •a decrease in the cost of crude oil feedstocks at the refineries, including a 14.5% decrease in the average cost of WTI Cushing crude oil and a 14.7% decrease in the average cost of WTI Midland crude oil; •small refinery exemptions received in 2025 resulting in a reduction of our Consolidated Net RINs Obligation and therefore a reduction within Cost of materials and other of approximately $356.1 million; and •in our logistics segment, decreased cost of materials and other of $7.2 million in our West Texas marketing operations. These decreases were partially offset by the following: •increased sales volume (including purchased products); and •incremental costs associated with the Gravity and H2O Midstream Acquisitions of $15.9 million and $3.0 million, respectively. Insurance Proceeds 2025 vs. 2024 Insurance proceeds were $0.1 million for the year ended December 31, 2025 compared to $20.6 million for the year ended December 31, 2024, a decrease of $20.5 million, or (99.5)%. The decrease was primarily driven by the following: •For the year ended December 31, 2025, we recognized $0.1 million of business interruption insurance recoveries compared to $20.6 million of insurance proceeds related to property damage from the 2021 El Dorado refinery fire, the 2021 freeze events and the 2022 Big Spring refinery fire for the year ended December 31, 2024. Refer to Note 14 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for further information. 69 | Management's Discussion and Analysis Operating Expenses 2025 vs. 2024 Operating expenses (included in both cost of sales and other operating expenses) were $871.9 million for the year ended December 31, 2025 compared to $767.2 million for the year ended December 31, 2024, an increase of $104.7 million, or 13.6%. The increase in operating expenses was primarily driven by the following: •an increase in outside services $20.8 million, variable expenses including natural gas, chemical, and electric of $41.1 million, employee costs of $46.3 million and maintenance costs of $13.2 million. These increases include costs associated with the H2O Midstream and Gravity Acquisitions of $10.6 million and $31.0 million, respectively. •These increases were partially offset by a decrease in insurance costs of $6.6 million and lease and rental costs of $11.0 million. General and Administrative Expenses 2025 vs. 2024 General and administrative expenses were $269.5 million for the year ended December 31, 2025 compared to $252.8 million for the year ended December 31, 2024, an increase of $16.7 million, or 6.6%. The increase was primarily driven by increased restructuring costs of $59.6 million and incentive compensation of $14.0 million. The increases were partially offset by decreased employee costs of $39.4 million and transaction costs of $15.8 million associated with the H20 Midstream Acquisition and Gravity Acquisition during the year ended December 31, 2024 and transaction costs associated with amended and new agreements with Delek Logistics during the year ended December 31, 2024. Depreciation and Amortization 2025 vs. 2024 Depreciation and amortization (included in both cost of sales and other operating expenses) was $397.8 million for the year ended December 31, 2025 compared to $374.5 million for the year ended December 31, 2024, an increase of $23.3 million, or 6.2%. The increase was a result of a general increase in our fixed asset base due to capital projects and turnarounds completed and depreciation and amortization attributable to the H2O Midstream and Gravity acquisitions. Asset Impairment 2025 vs. 2024 Asset impairment was $17.7 million for the year ended December 31, 2025 compared to $243.5 million for the year ended December 31, 2024. •For the year ended December 31, 2025, the asset impairment primarily related to an $11.6 million impairment of software development costs. •For the year ended December 31, 2024 we recorded a $22.1 million asset impairment as a result of our second quarter 2024 decision to idle our biodiesel facilities, while exploring viable and sustainable alternatives, recorded a $9.2 million asset impairment for pipeline assets because utilization was no longer probable and recorded a $212.2 million goodwill impairment. Refer to Note 13 and Note 20 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for further information. Other Operating Expense (Income), Net 2025 vs. 2024 Other operating income, net was $8.5 million and $55.5 million for the years ended December 31, 2025 and 2024, respectively, a decrease of $47.0 million, or (84.7)% . The decrease was primarily driven by the following: •for the year ended December 31, 2024, we recorded a net gain of $53.4 million in the 2024 period related to a property settlement; •for the year ended December 31, 2024, we recorded a gain of $16.5 million while for the year ended December 31, 2025, we recorded a gain of $2.8 million related to the 2021 El Dorado refinery fire; and •for the year ended December 31, 2024, we recorded a gain of $8.3 million related to Delek Logistics' eminent domain settlement while for the year ended December 31, 2025, we recorded a gain of $4.3 related to Delek Logistics' eminent domain settlement. 70 | Management's Discussion and Analysis These decreases were partially offset by the following: •for the year ended December 31, 2024, we made a strategic decision to abandon certain capital projects included in construction in progress that no longer fit our core objectives and as a result we recognized a loss of $14.1 million; and •for the year ended December 31, 2025 we recorded a $5.0 million gain on sale of an asset. Non-Operating Expenses, Net Interest Expense, Net 2025 vs. 2024 Interest expense, net was $345.3 million in the year ended December 31, 2025, compared to $313.0 million for year ended December 31, 2024, an increase of $32.3 million, or 10.3% primarily due to the following: •an increase in net average borrowings outstanding (including the obligations under the inventory intermediation agreement which has an associated interest charge) of approximately $172.6 million during the year ended December 31, 2025 (calculated as a simple average of beginning borrowings/obligation and ending borrowings/obligation for the period) compared to the year ended December 31, 2024; and •hedge loss associated with our interest rate swap. This increase was partially offset by the following: •a decrease in the average effective interest rate of 6 basis points during the year ended December 31, 2025 compared to the year ended December 31, 2024 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding). Results from Equity Method Investments 2025 vs. 2024 We recognized income from equity method investments of $89.5 million for the year ended December 31, 2025, compared to $92.2 million for the year ended December 31, 2024, a decrease of $2.7 million. This decrease was primarily driven by the following: •a decrease in income from our investment in Red River Pipeline Company LLC to $10.9 million during the year ended December 31, 2025 from $20.4 million in the year ended December 31, 2024; •a decrease in income from our investment in two other pipeline joint ventures to $7.4 million during the year ended December 31, 2025 from $11.8 million in the year ended December 31, 2024; and •a decrease in income from our asphalt terminal equity method investment due to lower volumes and resulting revenue decreases. These decreases was partially offset by the following: •an increase in income from our investment in W2W Holdings LLC to $43.2 million during the year ended December 31, 2025 from $28.9 million in the year ended December 31, 2024. Other Expense (Income), net 2025 vs. 2024 Other expense (income), net was $6.3 million of expense in the year ended December 31, 2025, compared to $6.3 million of income for the year ended December 31, 2024, an increase of $12.6 million, or 200.0% primarily due to the following: •an impairment recognized on two investments held at cost within other non-current assets for $8.6 million; and •a pension settlement of $2.1 million. Refer to Note 13 and Note 23 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for further information. Income Taxes 2025 vs. 2024 For the year ended December 31, 2025, we recorded an income tax benefit of $6.8 million from continuing operations compared to an income tax benefit of $107.9 million from continuing operations for the year ended December 31, 2024, primarily driven by the following: •an increase to pre-tax income of $38.9 million in the year ended December 31, 2025 compared to a pre-tax loss of $706.0 million in the year ended December 31, 2024; and 71 | Management's Discussion and Analysis •our effective tax rates were (17.5)% and 15.3% for the year ended December 31, 2025 and 2024, respectively, due to the impact of fixed dollar favorable permanent differences and changes in valuation allowance on certain attributes. Refer to Note 15 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for further information. 72 | Management's Discussion and Analysis Refining Segment The tables and charts below set forth selected information concerning our refining segment operations ($ in millions, except per barrel amounts): Selected Refining Financial Information Year Ended December 31, 2025 2024 2023 Revenues $ 10,551.3  $ 11,783.0  $ 16,406.9  Cost of materials and other 9,157.4  11,147.4  15,242.3  Refining Margin $ 1,393.9  $ 635.6  $ 1,164.6  Operating expenses (excluding depreciation and amortization) $ 614.6  $ 596.6  $ 619.2  Refining segment EBITDA $ 800.7  $ (158.0) $ 560.7  Factors Impacting Refining Profitability Our profitability in the refining segment is substantially determined by the difference between the cost of the crude oil feedstocks we purchase and the price of the refined products we sell, referred to as the "crack spread", "refining margin" or "refined product margin". Refining margin is used as a metric to assess a refinery's product margins against market crack spread trends, where "crack spread" is a measure of the difference between market prices for crude oil and refined products and is a commonly used proxy within the industry to estimate or identify trends in refining margins. The cost to acquire feedstocks and the price of the refined petroleum products we ultimately sell from our refineries depend on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions such as hurricanes or tornadoes, local, domestic and foreign political affairs, global conflict, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Other significant factors that influence our results in the refining segment include operating costs (particularly the cost of natural gas used for fuel and the cost of electricity), seasonal factors, refinery utilization rates and planned or unplanned maintenance activities or turnarounds. Moreover, while the fluctuations in the cost of crude oil are typically reflected in the prices of light refined products, such as gasoline and diesel fuel, the price of other residual products, such as asphalt, coke, carbon black oil and liquefied petroleum gas LPG are less likely to move in parallel with crude cost. This could cause additional pressure on our realized margin during periods of rising or falling crude oil prices. Additionally, our margins are impacted by the pricing differentials of the various types and sources of crude oil we use at our refineries and their relation to product pricing. Our crude slate is predominantly comprised of WTI crude oil. Therefore, favorable differentials of WTI compared to other crude will favorably impact our operating results, and vice versa. Additionally, because of our gathering system presence in the Midland area and the significant source of crude specifically from that region into our network, a widening of the WTI Cushing less WTI Midland spread will favorably influence the operating margin for our refineries. Alternatively, a narrowing of this differential will have an adverse effect on our operating margins. Global product prices are influenced by the price of Brent, which is a global benchmark crude. Global product prices influence product prices in the U.S. As a result, our refineries are influenced by the spread between Brent and WTI Midland. The Brent less WTI Midland spread represents the differential between the average per barrel price of Brent crude oil and the average per barrel price of WTI Midland crude oil. A widening of the spread between Brent and WTI Midland will favorably influence our refineries' operating margins. Also, the Krotz Springs refinery is influenced by the spread between Brent and LLS. The Brent less LLS spread represents the differential between the average per barrel price of Brent and the average per barrel price of LLS crude oil. A discount in LLS relative to Brent will favorably influence the Krotz Springs refinery operating margin. Finally, Refining EBITDA is impacted by regulatory costs associated with the cost of RINs as well as energy costs, including the cost of natural gas. In periods of unfavorable regulatory sentiment, RINs prices can increase at higher rates than crack spreads, or even when crack spreads are declining. This can be particularly impactful on smaller refineries, where the operating cost structure does not have as much scalability as larger refineries. Additionally, volatility in energy costs, which are captured in our operating expenses and impact our Refining EBITDA, can significantly impact our ability to capture crack spreads, with natural gas representing the most significant component. Within Delek’s geographic footprint, we source the majority of our natural gas from the Gulf Coast, and secondarily from the Permian Basin, and we do not currently have the capability at our refineries to switch our energy consumption to utilize alternative sources of fuel. For this reason, unfavorable Gulf Coast (Henry Hub) differentials can impact our crack spread capture. 73 | Management's Discussion and Analysis The cost to acquire the refined fuel products we sell to our wholesale customers in our logistics segment largely depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. In addition to the above, it continues to be a strategic and operational objective to manage price and supply risk related to crude oil that is used in refinery production, and to develop strategic sourcing relationships. For that purpose, from a pricing perspective, we enter into commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil and ethanol, future sales of refined products or to fix margins on future production. We also enter into future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage our RINs Obligation. Additionally, from a sourcing perspective, we often enter into purchase and sale contracts with vendors and customers or take physical or financial commodity positions for crude oil that may not be used immediately in production, but that may be used to manage the overall supply and availability of crude expected to ultimately be needed for production and/or to meet minimum requirements under strategic pipeline arrangements, and also to optimize and hedge availability risks associated with crude that we ultimately expect to use in production. Such transactions are inherently based on certain assumptions and judgments made about the current and possible future availability of crude. Therefore, when we take physical or financial positions for optimization purposes, our intent is generally to take offsetting positions in quantities and at prices that will advance these objectives while minimizing our positional and financial statement risk. However, because of the volatility of the market in terms of pricing and availability, it is possible that we may have material positions with timing differences or, more rarely, that we are unable to cover a position with an offsetting position as intended. Such differences could have a material impact on the classification of resulting gains/losses, assets or liabilities, and could also significantly impact Refining EBITDA. Refinery Statistics Year Ended December 31, 2025 2024 2023 Total Refining Segment Days in period 365  366  365  Total sales volume - refined product (average bpd) (1) 306,152  301,834  298,617  Total production (average bpd) 299,836  292,817  291,802  Crude oil 285,496  281,271  278,231  Other feedstocks 18,161  15,380  15,998  Total throughput (average bpd): 303,657  296,651  294,229  Crude Slate: (% based on amount received in period) WTI crude oil 75.0  % 69.9  % 73.0  % Gulf Coast Sweet Crude 6.3  % 7.3  % 4.3  % Local Arkansas crude oil 3.4  % 3.4  % 4.0  % Other 15.3  % 19.4  % 18.7  % Crude utilization (% based on nameplate capacity) 94.5  % 93.1  % 92.1  % 74 | Management's Discussion and Analysis Refinery Statistics (continued) Year Ended December 31, 2025 2024 2023 Tyler, TX Refinery Days in period 365  366  365  Products manufactured (average bpd): Gasoline 38,055  35,723  33,442  Diesel/Jet 32,470  31,755  28,670  Petrochemicals, LPG, natural gas liquids ("NGLs") 2,051  2,319  2,341  Other 855  849  1,691  Total production 73,431  70,646  66,144  Throughput (average bpd): Crude Oil 73,091  70,009  63,210  Other feedstocks 1,922  2,299  3,617  Total throughput 75,013  72,308  66,827  Per barrel of throughput: Operating expenses $ 5.02  $ 5.04  $ 5.08  Crude Slate: (% based on amount received in period) WTI crude oil 74.8  % 79.2  % 79.5  % East Texas crude oil 22.9  % 20.4  % 20.5  % Other 2.3  % 0.4  % —  % El Dorado, AR Refinery Days in period 365  366  365  Products manufactured (average bpd): Gasoline 38,138  38,215  38,868  Diesel/Jet 29,118  29,843  30,061  Petrochemicals, LPG, NGLs 1,097  1,205  1,495  Asphalt 6,749  8,739  7,711  Other 1,149  1,237  877  Total production 76,251  79,239  79,012  Throughput (average bpd): Crude Oil 74,712  77,993  77,423  Other feedstocks 2,960  2,886  3,262  Total throughput 77,672  80,879  80,685  Per barrel of throughput: Operating expenses $ 4.86  $ 4.65  $ 4.59  Crude Slate: (% based on amount received in period) WTI crude oil 81.0  % 66.5  % 67.3  % Local Arkansas crude oil 13.2  % 12.2  % 14.0  % Other 5.8  % 21.3  % 18.7  % 75 | Management's Discussion and Analysis Refinery Statistics (continued) Year Ended December 31, 2025 2024 2023 Big Spring, TX Refinery Days in period 365  366  365  Products manufactured (average bpd): Gasoline 33,227  33,888  32,386  Diesel/Jet 23,403  25,157  22,390  Petrochemicals, LPG, NGLs 3,139  4,710  3,593  Asphalt 2,003  2,774  1,983  Other 3,982  3,883  3,129  Total production 65,754  70,412  63,481  Throughput (average bpd): Crude oil 63,145  66,123  60,236  Other feedstocks 3,871  4,975  4,223  Total throughput 67,016  71,098  64,459  Per barrel of refined throughput: Operating expenses $ 7.11  $ 6.66  $ 7.92  Crude Slate: (% based on amount received in period) WTI crude oil 74.0  % 70.4  % 68.5  % WTS crude oil 26.0  % 29.6  % 31.5  % Krotz Springs, LA Refinery Days in period 365  366  365  Products manufactured (average bpd): Gasoline 42,614  34,268  40,805  Diesel/Jet 32,070  28,125  31,589  Heavy Oils 3,260  3,641  3,785  Petrochemicals, LPG, NGLs 6,456  4,942  6,525  Other —  1,544  460  Total production 84,400  72,520  83,164  Throughput (average bpd): Crude Oil 74,548  67,146  77,362  Other feedstocks 9,408  5,220  4,896  Total throughput 83,956  72,366  82,258  Per barrel of throughput: Operating expenses $ 5.22  $ 5.23  $ 4.96  Crude Slate: (% based on amount received in period) WTI Crude 69.9  % 63.7  % 77.4  % Gulf Coast Sweet Crude 24.1  % 29.7  % 15.1  % Other 6.0  % 6.6  % 7.5  % (1)     Includes inter-refinery sales and sales to other segments which are eliminated in consolidation. See tables below. 76 | Management's Discussion and Analysis Included in the refinery statistics above are the following sales to other segments: Refinery Sales to Other Segments Year Ended December 31, (in barrels per day) 2025 2024 2023 Big Spring refined product sales to other Delek segments 10,575  18,053  21,165  Pricing Statistics (average for the period presented) Year Ended December 31, 2025 2024 2023 WTI — Cushing crude oil (per barrel) $ 64.87  $ 75.88  $ 77.69  WTI — Midland crude oil (per barrel) $ 65.59  $ 76.85  $ 78.90  WTS — Midland crude oil (per barrel) $ 64.71  $ 75.95  $ 77.61  LLS (per barrel) $ 67.15  $ 78.30  $ 80.18  Brent (per barrel) $ 68.19  $ 79.84  $ 82.21  U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1) $ 20.42  $ 17.58  $ 27.02  U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1) $ 19.56  $ 16.94  $ 25.93  U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1) $ 15.83  $ 13.40  $ 14.70  U.S. Gulf Coast unleaded gasoline (per gallon) $ 1.91  $ 2.13  $ 2.34  Gulf Coast ultra-low sulfur diesel (per gallon) $ 2.21  $ 2.36  $ 2.72  U.S. Gulf Coast high sulfur diesel (per gallon) $ 2.00  $ 1.98  $ 1.85  Natural gas (per MMBTU) $ 3.62  $ 2.42  $ 2.66  (1)For our Tyler and El Dorado refineries, we compare our per barrel refining product margin to the Gulf Coast 5-3-2 crack spread consisting of (Argus pricing) WTI Cushing crude, U.S. Gulf Coast CBOB gasoline and Gulf Coast ultra-low sulfur diesel. For our Big Spring refinery, we compare our per barrel refining margin to the Gulf Coast 3-2-1 crack spread consisting of (Argus pricing) WTI Cushing crude, U.S. Gulf Coast CBOB gasoline and Gulf Coast ultra-low sulfur diesel. For our Krotz Springs refinery, we compare our per barrel refining margin to the Gulf Coast 2-1-1 crack spread consisting of (Argus pricing) LLS crude oil, (Argus pricing) U.S. Gulf Coast CBOB gasoline and (Platts pricing) U.S. Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). The Tyler refinery's crude oil input is primarily WTI Midland and East Texas, while the El Dorado refinery's crude input is primarily a combination of WTI Midland, local Arkansas and other domestic inland crude oil. The Big Spring refinery’s crude oil input is primarily comprised of WTS and WTI Midland. The Krotz Springs refinery’s crude oil input is primarily comprised of LLS and WTI Midland. 77 | Management's Discussion and Analysis Refining Segment Operational Comparison of the Year Ended December 31, 2025 versus the Year Ended December 31, 2024 Revenues 2025 vs. 2024 Revenues for the refining segment decreased $1,231.7 million, or 10.5%, in the year ended December 31, 2025 compared to the year ended December 31, 2024. The decrease was primarily driven by the following: •a decrease in the average price of U.S. Gulf Coast gasoline of 10.3% and ULSD of 6.4%. These decreases were partially offset by the following: •an increase in sales volumes (including purchased products); •an increase in the average price of U.S. Gulf Coast HSD of 1.0%. Revenues included sales to our logistics segment of $342.2 million and $353.5 million for the year ended December 31, 2025 and 2024, respectively. We eliminate this intercompany revenue in consolidation. Cost of Materials and Other 2025 vs. 2024 Cost of materials and other decreased $1,990.0 million, or 17.9%, in the year ended December 31, 2025 compared to the year ended December 31, 2024. This decrease was primarily driven by the following: •decreases in the cost of WTI Cushing crude oil, from an average of $75.88 per barrel to an average of $64.87, or 14.5%; and decreases in the cost of WTI Midland crude oil, from an average of $76.85 per barrel to an average of $65.59, or 14.7%; •small refinery exemptions received in the third quarter of 2025 resulting in a reduction of our Consolidated Net RINs Obligation and therefore a reduction within Cost of materials and other of approximately $356.1 million; and •a decrease in lease expense as a result of reclassification of certain fees with Delek Logistics from lease expense to interest expense under finance lease accounting. These finance leases have no impact to the Delek US consolidated results as these amounts eliminate in consolidation. These decreases were partially offset by the following: •an increase in sales volumes (including purchased products). Our refining segment purchases finished product from our logistics segment and has multiple service agreements with our logistics segment which, among other things, require the refining segment to pay terminalling and storage fees based on the throughput volume of crude and finished product in the logistics segment pipelines and the volume of crude and finished product stored in the logistics segment storage tanks, subject to minimum volume commitments. These costs and fees were $499.0 million and $516.3 million during the years ended December 31, 2025 and 2024, respectively. We eliminate these intercompany fees in consolidation. Operating Expenses 2025 vs. 2024 Operating expenses increased $18.0 million, or 3.0%, in the year ended December 31, 2025, compared to the year ended December 31, 2024. The increase in operating expenses was primarily driven by the following: •higher natural gas prices in 2025 and an increase in outside services. •These increases were partially offset by a decrease in insurance costs and a decrease in lease and rental costs. Refining Margin 2025 vs. 2024 Refining margin increased by $758.3 million, or 119.3%, for the year ended December 31, 2025 compared to the year ended December 31, 2024, with a refining margin percentage of 13.2% as compared to 5.4% for the years ended December 31, 2025 and 2024, respectively, primarily driven by the following: •a 16.2% increase in the Gulf Coast 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery), a 15.5% increase in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery) and a 18.1% increase in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery); 78 | Management's Discussion and Analysis •small refinery exemptions received in the third quarter of 2025 resulting in a reduction of our Consolidated Net RINs Obligation and therefore a reduction within Cost of materials and other of approximately $356.1 million; •an increase in sales volumes (including purchased products); and •a decrease in lease expense as a result of reclassification of certain fees with Delek Logistics from lease expense to interest expense under finance lease accounting. These finance leases have no impact to the Delek US consolidated results as these amounts eliminate in consolidation. EBITDA 2025 vs. 2024 EBITDA increased by $958.7 million, or 606.8% for the year ended December 31, 2025 compared to the year ended December 31, 2024, primarily due to an increase in refining margin driven by increased crack spreads, increased sales volumes and receipt of small refinery exemptions. 79 | Management's Discussion and Analysis Logistics Segment The table below sets forth certain information concerning our logistics segment operations ($ in millions, except per barrel amounts): Selected Logistics Financial and Operating Information Year Ended December 31, 2025 2024 2023 Revenues $ 1,013.3  $ 940.6  $ 1,020.4  Cost of materials and other $ 509.3  $ 483.7  $ 532.6  Operating expenses (excluding depreciation and amortization) $ 168.4  $ 122.7  $ 118.1  EBITDA $ 369.3  $ 342.7  $ 363.0  Operating Information: Gathering & Processing: (average bpd) Lion Pipeline System: Crude pipelines (non-gathered) 66,125  69,903  67,003  Refined products pipelines 54,616  59,136  58,181  SALA Gathering System 9,454  11,568 13,782 East Texas Crude Logistics System 31,296  34,711 32,668 Midland Gathering Assets 219,782  217,847 230,471 Plains Connection System 182,523  333,405  250,140  Delaware Gathering Assets: Natural gas gathering and processing (Mcfd) (1) 62,111  74,831  71,239  Crude oil gathering (average bpd) 138,575  123,978  111,335  Water disposal and recycling (average bpd) 107,415  128,539  108,907  Midland Water Gathering System: Water disposal and recycling (average bpd) 587,419  280,955  —  Wholesale Marketing & Terminalling: East Texas - Tyler refinery sales volumes (average bpd) (2) 68,052  67,682  60,626  Big Spring wholesale marketing throughputs (average bpd) —  44,999  77,897  West Texas wholesale marketing throughputs (average bpd) 8,737  5,828  10,032  West Texas wholesale marketing margin per barrel $ 3.42  $ 3.18  $ 5.18  Terminalling throughputs (average bpd) (3) 145,237  154,217  113,803  (1)     Mcfd - average thousand cubic feet per day. (2)     Excludes jet fuel and petroleum coke. (3)     Consists of terminalling throughputs at our Tyler, Big Spring, Big Sandy and Mount Pleasant, Texas terminals, El Dorado and North Little Rock, Arkansas terminals and Memphis and Nashville, Tennessee terminals. Logistics revenue is largely based on fixed-fee or tariff rates charged for throughput volumes running through our logistics network, where many of those volumes are contractually protected by minimum volume commitments ("MVCs"). To the extent that our logistics volumes are not subject to MVCs, our Logistics revenue may be negatively impacted in periods where our customers are experiencing economic pressures or reductions in demand for their products. Additionally, certain of our throughput arrangements contain deficiency credit provisions that may require us to defer excess MVC fees collected over actual throughputs to apply toward MVC deficiencies in future periods. With respect to our equity method investments in pipeline joint ventures, our earnings from those investments (which is based on our pro rata ownership percentage of the joint venture's recognized net income or loss) are directly impacted by the operations of those joint ventures. Items impacting the joint venture net income (loss) may include (but are not limited to) the following: long-term throughput contractual arrangements and related MVCs and, in some cases, deficiency credit provisions; the demand for walk-up nominations; applicable rates or tariffs; long-lived asset or other impairments assessed at the joint venture level; and pipeline releases or other contingent liabilities. With respect to our West Texas marketing activities, our profitability is dependent upon the cost of landed product versus the rack price of refined product sold. Our logistics segment is generally protected from commodity price risk because inventory is purchased and then immediately sold at the rack. 80 | Management's Discussion and Analysis Logistics Segment Operational Comparison of the Year Ended December 31, 2025 versus the Year Ended December 31, 2024 Revenues 2025 vs. 2024 Net revenues increased by $72.7 million, or 7.7%, in the year ended December 31, 2025 compared to the year ended December 31, 2024 primarily driven by the following: •incremental revenue associated with the Gravity acquisition of $90.1 million and incremental revenue associated with the H2O Midstream acquisition of $41.0 million. This increase was partially offset by the following: •decreased revenue of $5.6 million in our West Texas marketing operations primarily driven by a decrease in average sales prices per gallon, partially offset by an increase in volumes sold and an increase in RINs revenue: ◦the average sales prices per gallon of gasoline and diesel sold decreased by $0.21 and $0.16 per gallon, respectively; ◦the volumes of diesel sold increased by 6.7 million and the volumes of gasoline sold increased by 2.2 million gallons; and ◦RINs revenue increased $3.7 million due to increased RINs prices. •decreased revenue due to recording certain throughput fees as interest income under sales-type lease accounting, whereas these fees were recognized as revenue during part of the prior year period; and •decrease of $12.1 million due to the assignment of the Big Spring Refinery marketing agreement to Delek Holdings in the third quarter of 2024. Revenues included sales to our refining segment of $499.0 million and $516.3 million for the years ended December 31, 2025 and 2024, respectively, and sales to corporate and other of $0.5 million and $1.5 million for the years ended December 31, 2025 and 2024, respectively. We eliminate this intercompany revenue in consolidation. Cost of Materials and Other 2025 vs. 2024 Cost of materials and other for the logistics segment increased by $25.6 million, or 5.3%, in the year ended December 31, 2025 compared to the year ended December 31, 2024. This increase was primarily driven by the following: •incremental costs associated with the Gravity and H2O Midstream Acquisitions of $15.9 million and $3.0 million, respectively; and •an increase of $11.2 million associated with the DPG dropdown which occurred on May 1, 2025. These increases were partially offset by the following: •decreased costs of materials and other of $7.2 million in our West Texas marketing operations was primarily driven by a decrease in average cost per gallon, partially offset by an increase in volumes sold: ◦the average cost per gallon of gasoline and diesel sold decreased by $0.18 per gallon and $0.17 per gallon, respectively; ◦the volumes of diesel sold increased by 6.7 million gallons, and the volumes of gasoline sold increased by 2.2 million. Our logistics segment purchased product from our refining segment for $342.2 million and $353.5 million for the years ended December 31, 2025 and December 31, 2024, respectively. We eliminate these intercompany costs in consolidation. 81 | Management's Discussion and Analysis Operating Expenses 2025 vs. 2024 Operating expenses increased by $45.7 million, or 37.2%, in the year ended December 31, 2025 compared to the year ended December 31, 2024, primarily driven by the following: •incremental costs associated with the operations of Gravity and H2O Midstream of $31.0 million and $10.6 million, respectively. EBITDA 2025 vs. 2024 EBITDA increased by $26.6 million, or 7.8%, in the year ended December 31, 2025 compared to the year ended December 31, 2024, primarily driven by the following: •incremental EBITDA of $42.6 million and $26.7 million associated with the Gravity and H2O Midstream Acquisitions, respectively; and • an $0.24 per barrel increase in wholesale margins. These increases were partially offset by the following: •recording certain throughput and storage fees in interest income due to sales-type lease accounting that were previously recorded as revenue in prior year period; and •lower revenue due to the assignment of the Big Spring refinery marketing agreement to Delek Holdings. A detailed discussion of the fiscal year 2024 compared to year-over-year changes from fiscal year 2023 can be found in Part II, Item 7. Management's Discussion and Analysis, "Results of Operations", of our 2024 Annual Report on Form 10-K, filed on February 26, 2025. 82 | Management's Discussion and Analysis Liquidity and Capital Resources Sources of Capital Our primary sources of liquidity and capital resources are •cash generated from our operating activities; •borrowings under our debt facilities; and •potential issuances of additional equity and debt securities. At December 31, 2025, our total liquidity amounted to $2,246.6 million comprised primarily of $1,620.8 million in unused credit commitments under our revolving credit facilities (as discussed in Note 11 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K) and $625.8 million in cash and cash equivalents. Historically, we have generated adequate cash from operations to fund ongoing working capital requirements, pay quarterly cash dividends, repurchase common stock and fund operational capital expenditures. On February 18, 2026, our Board of Directors approved a quarterly cash dividend of $0.2550 per share of our common stock. During the year ended December 31, 2025, 3,839,968 shares of our common stock were repurchased and cancelled at the time of the transaction for a total of $79.4 million. As of December 31, 2025, there was $464.2 million of authorization remaining under Delek's aggregate stock repurchase program. Other funding sources including borrowings under existing credit agreements and issuance of equity and debt securities have been utilized to meet our funding requirements and support our growth capital projects and acquisitions. In addition, we have historically been able to source funding at terms that reflect market conditions, our financial position and our credit ratings and expect future funding sources to be at terms that are sustainable and profitable for the Company. However, there can be no assurances regarding the availability of future debt or equity financings or whether such financings can be made available on terms that are acceptable to us; any execution of such financing activities will be dependent on the contemporaneous availability of functioning debt or equity markets. Additionally, new debt financing activities will be subject to the satisfaction of any debt incurrence limitation covenants in our existing financing agreements. Our debt limitation covenants in our existing financing documents are usual and customary for credit agreements of our type and reflective of market conditions at the time of their execution. Additionally, our ability to satisfy working capital requirements, to service our debt obligations, to fund planned capital expenditures, to pay dividends and repurchase common stock will depend upon future operating performance, which will be affected by prevailing economic conditions in the oil industry and other financial and business factors, including oil prices, some of which are beyond our control. As of December 31, 2025, we believe we were in compliance with all of our debt maintenance covenants, where the most significant long-term obligation subject to such covenants was the Delek Term Loan Credit Facility (see further discussion in Note 11 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K). Additionally, we were in compliance with covenants during the quarter ended December 31, 2025. Failure to meet the incurrence covenants could impose certain incremental restrictions on our ability to incur new debt and also may limit whether and the extent to which we may pay dividends, as well as impose additional restrictions on our ability to repurchase our stock, make new investments and incur new liens (among others). Such restrictions would generally remain in place until such a quarter that we return to compliance under the applicable incurrence based covenants. In the event that we are subject to these incremental restrictions, we believe that we have sufficient current and alternative sources of liquidity, including (but not limited to): available borrowings under our existing Delek Revolving Credit Facility, and for Delek Logistics, under its Delek Logistics Revolving Facility; the allowance to incur an additional $400.0 million of secured debt under the Delek Term Loan Credit Facility (see further discussion of these facilities in Note 11 of our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K); the ability to nominate each month whether to include volumes related to the Krotz Springs, El Dorado and Big Spring refineries for funding under the Inventory Intermediation Agreement; as well as the possibility of obtaining other secured and unsecured debt, raising capital through equity issuance, or taking advantage of transactional financing opportunities such as sale-leasebacks or joint ventures, as otherwise contemplated and allowed under our incurrence covenants. 83 | Management's Discussion and Analysis Cash Flows The following table sets forth a summary of our consolidated cash flows (in millions): Consolidated Year Ended December 31, 2025 2024 Cash Flow Data: Operating activities - continuing operations $ 538.2  $ (83.7) Operating activities - discontinued operations (2.4) 16.9  Total Operating activities 535.8  (66.8) Investing activities - continuing operations (697.9) (603.2) Investing activities - discontinued operations —  361.7  Total Investing activities (697.9) (241.5) Financing activities - continuing operations 52.3  221.7  Total Financing activities 52.3  221.7  Net (decrease) increase $ (109.8) $ (86.6) Cash Flows from Operating Activities Continuing Operations Net cash provided by operating activities from continuing operations was $538.2 million for the year ended December 31, 2025, compared to net cash used of $83.7 million for the comparable period of 2024. The increases were a result of cash receipts from customers and cash payments to suppliers and for salaries resulting in a net $689.5 million increase in cash provided by operating activities partially offset by an increase in cash paid for debt interest of $41.6 million. During 2025 the receipt of SRE waivers resulted cash inflows due to the selling of excess RINs as well as reducing our need to purchase RINs related to certain refineries. Cash Flows from Investing Activities Continuing Operations Net cash used in investing activities from continuing operations was $697.9 million for the year ended December 31, 2025, compared to $603.2 million in the comparable period of 2024. The increase in cash flows used in investing activities was primarily due to the $101.8 million increase in purchases of property, plant and equipment and a reduction in insurance and settlement proceeds of $5.5 million. Cash Flows from Financing Activities Continuing Operations Net cash provided by financing activities from continuing operations was $52.3 million for the year ended December 31, 2025, compared to cash provided of $221.7 million in the comparable 2024 period. The decrease in cash provided was primarily due to net payments on long-term revolvers of $223.5 million for the year ended December 31, 2025 compared to net payments of $350.1 million in the comparable 2024 period, net proceeds on product and other financing arrangements of $28.9 million for the year ended December 31, 2025 compared to net proceeds of $14.0 million in the comparable 2024 period and net proceeds of term debt of $690.5 million for the year ended December 31, 2025 compared to net proceeds on term debt of $518.2 million in the comparable 2024 period, primarily related to the issuance of the Delek Logistics 2033 Notes and the related repayment on the Delek Logistics Revolving Facility. These increases in cash flows were partially offset by the receipt of net proceeds of $297.9 million from the Delek Logistics' public offerings of common units in the year ended December 31, 2024, an increase of $37.9 million in share buybacks, repayments on the Inventory Intermediation agreement of $193.2 million and a $30.3 million increase in distributions to non-controlling interests. Cash Position and Indebtedness As of December 31, 2025, our total cash and cash equivalents were $625.8 million, and we had total long-term indebtedness of approximately $3,233.1 million. The total long-term indebtedness is net of deferred financing costs and debt discount of $50.2 million. Additionally, we had letters of credit issued of approximately $417.4 million. Total unused credit commitments or borrowing base availability, as applicable, under our revolving credit facilities was approximately $1,620.8 million. The increase of $466.9 million in total long-term principal indebtedness as of December 31, 2025 compared to December 31, 2024 resulted primarily from the issuance of the Delek Logistics 2033 Notes and a decrease in net borrowings under the Delek Logistics Revolving Facility. As of December 31, 2025, our total long-term indebtedness (as defined in Note 11 of the consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K) consisted of the following: •the Delek Revolving Credit Facility with no outstanding borrowings (maturity of October 26, 2027); 84 | Management's Discussion and Analysis •aggregate principal of $921.5 million under the Delek Term Loan Credit Facility (maturity of November 19, 2029 and effective interest of 8.23%); •aggregate principal of $211.8 million under the Delek Logistics Revolving Facility (maturity of October 13, 2027 and average borrowing rate of 6.58%); •aggregate principal of $400.0 million under the Delek Logistics 2028 Notes (due in 2028, with effective interest rate of 7.37%); •aggregate principal of $1,050.0 million under the Delek Logistics 2029 Notes (due in 2029, with effective interest rate of 8.80%); and •aggregate principal of $700.0 million under the Delek Logistics 2033 Notes (due in 2033, with effective interest rate of 7.63%). Additionally, we utilize other financing arrangements to finance operating assets and/or, from time to time, to monetize other assets that may not be needed in the near term when internal cost of capital and other criteria are met. Such arrangements include our inventory intermediation arrangement, which finances a significant portion of our first-in, first-out inventory at the refineries and, from time to time, RINs or other non-inventory product financing liabilities and funded letters of credit. Our long-term inventory intermediation obligation with Citi was $119.5 million at December 31, 2025. See Note 10 of the accompanying consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K for additional information about our inventory intermediation agreement. Our product financing liabilities consisted primarily of RIN financings as of December 31, 2025, and totaled $243.8 million, all of which is due in the next 12 months. See further description of these types of arrangements in the Environmental Credits and Related Regulatory Obligations accounting policy disclosed in Note 2 to our accompanying consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. For both arrangements and the related commitments, see also our "Cash Requirements" section below. Debt Ratings We receive debt ratings from the major ratings agencies in the U.S. In determining our debt ratings, the agencies consider a number of qualitative and quantitative items including, but not limited to, commodity pricing levels, our liquidity, asset quality, reserve mix, debt levels and seniorities, cost structure, planned asset sales and production growth opportunities. There are no "rating triggers" in any of our contractual debt obligations that would accelerate scheduled maturities should our debt rating fall below a specified level. However, a downgrade could adversely impact our interest rate on new credit facility borrowings and the ability to economically access debt markets in the future. Additionally, any rating downgrades may increase the likelihood of us having to post additional letters of credit or cash collateral under certain contractual arrangements. Capital Spending A key component of our long-term strategy is our capital expenditure program. The following table summarizes our actual capital expenditures for the year ended December 31, 2025, by operating segment and major category (in millions): 2026 Budget Year Ended December 31, 2025 Actual(1) Refining Regulatory $ 29  $ 16.4  Sustaining maintenance, including turnaround activities 192  188.8  Growth projects 1  1.5  Refining segment total 222  206.7  Logistics Regulatory 12  2.7  Sustaining maintenance 33  12.0  Growth projects 210  237.4  Logistics segment total 255  252.1  Corporate and Other Regulatory 3  3.4  Sustaining maintenance 10  15.1  Growth projects 5  12.7  Other total 18  31.2  Total capital spending $ 495  $ 490.0  (1) Amounts exclude capitalized interest and internal labor costs of $31.6 million. The amount of our capital expenditure forecast is subject to change due to unanticipated increases in the cost, scope, and completion time for our capital projects and subject to the changes and uncertainties discussed under the 'Forward-Looking Statements' section of Item 7. Management's Discussion and Analysis of this Annual Report on Form 10-K. For further information, please refer to our discussion in Item 1A. Risk Factors, of this Annual Report on Form 10-K. 85 | Management's Discussion and Analysis Cash Requirements Long-Term Cash Requirements Under Contractual Obligations Information regarding our known cash requirements under contractual obligations of the types described below as of December 31, 2025, is set forth in the following table (in millions): Payments Due by Period 1 Year 1-3 Years 3-5 Years 5 Years Total Long-term debt and notes payable obligations $ 9.5  $ 630.8  $ 1,943.0  $ 700.0  $ 3,283.3  Interest (1) 250.4  481.9  250.5  154.9  1,137.7  Operating lease commitments (2) 30.9  37.1  7.8  9.2  85.0  Purchase commitments (3) 1,189.3  23.3  —  —  1,212.6  Product financing agreements (4) 243.8  —  —  —  243.8  Transportation agreements (5) 172.4  238.9  198.2  106.3  715.8  Inventory intermediation obligation (6) 21.7  121.3  —  —  143.0  Retail Stores obligations (7) 8.6  17.2  15.6  2.6  44.0  Total $ 1,926.6  $ 1,550.5  $ 2,415.1  $ 973.0  $ 6,865.2  (1) Expected interest payments on debt outstanding at December 31, 2025. Floating interest rate debt is calculated using December 31, 2025 rates. For additional information, see Note 11 to the consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. (2) Amounts reflect future estimated lease payments under operating leases having remaining non-cancellable terms in excess of one year as of December 31, 2025. (3) We have purchase commitments to secure certain quantities of crude oil, finished product and other resources used in production at both fixed and market prices. We have estimated future payments under the market-based agreements using current market rates. Excludes purchase commitments in buy-sell transactions which have matching notional amounts with the same counterparty and are generally net settled in exchanges. (4) Balances consist of obligations under RINs product financing arrangements, as described in the ''Environmental Credits and Related Regulatory Obligations" accounting policy included in Note 2 to our consolidated financial statements in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. (5) Balances consist of contractual obligations under agreements with third parties (not including Delek Logistics) for the transportation of crude oil to our refineries. (6) Balances consist of contractual obligations under the Citi Inventory Intermediation Agreement, including principal obligation for the Baseline Volume Step-Out Liability and other recurring fees. For additional information, see Note 10 to the consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. (7) Amounts reflect a rebate arrangement included in the long-term agreement with FEMSA entered into in conjunction with the Retail Transaction as well as certain underground storage tank cleanup obligations. For additional information, see our consolidated financial statements in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. Other Cash Requirements Our material short-term cash requirements under contractual obligations are presented above, and we expect to fund the majority of those requirements with cash flows from operations. Our other cash requirements consisted of operating activities and capital expenditures. Operating activities include cash outflows related to payments to suppliers for crude and other inventories (which are largely reflected in our contractual purchase commitments in the table above) and payments for salaries and other employee related costs. Cash outlays in 2026 are planned to include incentive compensation payments that were earned and accrued in 2025. In line with our long-term sustainable strategy, future cash requirements will include initiatives to build on our long-term sustainable business model, Environmental, Social and Governance initiatives and sum of the parts initiatives. Refer to the cash flow section for our operating activities spend during the year ended December 31, 2025. While many of the expenses related to the operating activities are variable in nature, some of the expenditures can be somewhat fixed in the short-term due to forward planning on our level of activity. Refer to the 'Capital Spending' section for our capital expenditures for the year ended December 31, 2025 and our anticipated cash requirements for planned capital expenditures for the full year 2025. 86 | Management's Discussion and Analysis Critical Accounting Estimates The fundamental objective of financial reporting is to provide useful information that allows a reader to comprehend our business activities. We prepare our consolidated financial statements in conformity with GAAP, and in the process of applying these principles, we must make judgments, assumptions and estimates based on the best available information at the time. To aid a reader's understanding, management has identified our critical accounting policies. These policies are considered critical because they are both most important to the portrayal of our financial condition and results, and require our most difficult, subjective or complex judgments. Often, they require judgments and estimation about matters which are inherently uncertain and involve measuring at a specific point in time, events which are continuous in nature. Actual results may differ based on the accuracy of the information utilized and subsequent events, some over which we may have little or no control. Goodwill Goodwill in an acquisition represents the excess of the aggregate purchase price over the fair value of the identifiable net assets. Goodwill is reviewed at least annually for impairment, or more frequently if indicators of impairment exist, such as disruptions in our business, unexpected significant declines in operating results or a sustained market capitalization decline. Goodwill is evaluated for impairment by comparing the carrying amount of the reporting unit to its estimated fair value. In assessing the recoverability of goodwill, assumptions are made with respect to future business conditions and estimated expected future cash flows to determine the fair value of a reporting unit. We may consider inputs such as a market participant WACC, gross margin, future volumes, capital expenditures and long-term growth rates based on historical information and our best estimate of future forecasts, all of which are subject to significant judgment and estimates. We may also consider a market approach in determining or corroborating the fair values of the reporting units using a multiple of expected future cash flows, such as those used by third-party analysts. The market approach involves significant judgment, including selection of an appropriate peer group, selection of valuation multiples, and determination of the appropriate weighting in our valuation model. If these estimates and assumptions change in the future, due to factors such as a decline in general economic conditions, competitive pressures on sales and margins and other economic and industry factors beyond management's control, an impairment charge may be required. The most significant risks to our valuation and the potential future impairment of goodwill are the WACC and the volatility of the crack spread, which is based on the crude oil and the refined product markets. The crack spread is often unpredictable and may negatively impact our results of operations in ways that cannot be anticipated and that are beyond management's control. Additionally, rising interest rates (which often occur under inflationary conditions) may also adversely impact our WACC. A higher WACC, all other things being equal, will result in a lower valuation using a discounted cash flow model, which is an income approach. Therefore, rising interest rates can cause a reporting unit to become impaired when, in a lower interest rate environment, it may not be. We may also elect to perform a qualitative impairment assessment of goodwill balances. The qualitative assessment permits companies to assess whether it is more likely than not (i.e., a likelihood of greater than 50%) that the fair value of a reporting unit is less than its carrying amount. If a company concludes that, based on the qualitative assessment, it is more likely than not that the fair value of a reporting unit is less than its carrying amount, the company is required to perform the quantitative impairment test. Alternatively, if a company concludes based on the qualitative assessment that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, it has completed its goodwill impairment test and does not need to perform the quantitative impairment test. For the 2025 and 2024 annual impairment assessments, we performed a qualitative assessment on the reporting units in our logistics segment, which did not result in an impairment charge nor did our analysis reflect any reporting units at risk. For the 2023 annual impairment assessment, we performed a qualitative assessment on the reporting units in our logistics segment except for the Delaware Gathering reporting unit, as we determined it was more likely than not that the fair value of the reporting unit exceeded the carrying value. Our annual impairment assessment was performed on a quantitative basis for our Delaware Gathering reporting unit during the fourth quarter of 2023. As part of our 2023 annual assessment, we recorded a $14.8 million impairment charge in the fourth quarter of 2023 related to our Delaware Gathering reporting unit within the logistics segment, which brought the amount of goodwill recorded within this reporting unit to zero. The impairment was primarily driven by the significant increases in interest rates and timing effect of system connections with our producer customers. For the 2025 and 2023 annual impairment assessment, we performed a qualitative assessment on the reporting units in our refining segment, as we determined it was not more likely than not that the fair value of the reporting units exceeded the carrying value. The 2025 and 2023 annual assessments for the refining segment did not result in an impairment charge nor did our analysis reflect any reporting units at risk. For the 2024 annual impairment assessment, we performed a quantitative assessment of goodwill on the reporting units in our refining segment during the fourth quarter of 2024, which resulted in an impairment of $212.2 million during the year ended December 31, 2024 related to our Krotz Springs refinery reporting unit. The impairment was predominantly driven by depressed crack spread pricing in the near term combined with an increased discount rate. As part of our quantitative assessment, the aggregate fair value of all reporting units were reconciled to our market capitalization for reasonableness. Details of remaining goodwill balances by segment are included in Note 17 to the consolidated financial statements in Item 8. Financial Statements and Supplementary Data, of this Annual Report on Form 10-K. 87 | Management's Discussion and Analysis Business Combinations We recognize and measure the assets acquired and liabilities assumed in a business combination based on their estimated fair values at the acquisition date in accordance with the provisions of ASC 805, Business Combinations ("ASC 805"). Any excess or deficiency of the purchase consideration when compared to the fair value of the net tangible assets acquired, if any, is recorded as goodwill or gain from a bargain purchase. The fair value of assets and liabilities as of the acquisition date are often estimated using a combination of approaches, including the income approach, which requires us to project future cash flows and apply an appropriate discount rate; the cost approach, which requires estimates of replacement costs and depreciation and obsolescence estimates; and the market approach which uses market data and adjusts for entity-specific differences. We use all available information to make these fair value determinations and engage third-party consultants for valuation assistance. The estimates used in determining fair values are based on assumptions believed to be reasonable, but which are inherently uncertain. Accordingly, actual results may differ materially from the projected results used to determine fair value. New Accounting Pronouncements See Note 2 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 new accounting pronouncements applicable to us.