CVI 8-K
Cvr Energy Inc (CVI)
8-K
2026-01-05
For: 2025-12-31
View Original
Added on
April 07, 2026
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
___________________________________
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
___________________________________
Date of Report (Date of earliest event reported): December 31, 2025
(Exact name of registrant as specified in its charter)
(State or other jurisdiction of incorporation) | (Commission File Number) | (I.R.S. Employer Identification Number) | ||||||
(Address of principal executive offices, including zip code)
Registrant’s telephone number, including area code: (281 ) 207-3200
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Item 7.01. Regulation FD Disclosure
Partial Prepayment on Senior Secured Term Loan and Preliminary 2026 Capital Expenditure Outlook
On January 5, 2026, CVR Energy, Inc. (the “Company”) issued a press release announcing that on December 31, 2025, certain of its wholly owned subsidiaries prepaid $75 million in principal of the Company’s senior secured term loan credit facility (the “Term Loan”), reducing the total outstanding principal under the Term Loan to approximately $165 million. The press release also provides guidance concerning the Company’s 2026 preliminary capital expenditure estimates. The full text of the press release is attached as Exhibit 99.1 to this Current Report on Form 8-K (“Current Report”) and is incorporated herein by reference.
Investor Presentation
Beginning January 5, 2026, the Company will be using the Investor Presentation (the “Investor Presentation”), which contains forward-looking statements, in meetings with certain current and potential investors and analysts. The Investor Presentation, available on the Investor Relations page of the Company’s website at www.CVREnergy.com, is furnished as Exhibit 99.2 to this Current Report and is incorporated herein by reference.
The information in this Current Report and Exhibits 99.1 and 99.2 is being furnished, not filed, pursuant to Items 7.01 and 9.01 of Form 8-K. Accordingly, the information in Items 7.01 and 9.01 of this Current Report, including Exhibits 99.1 and 99.2, will not be subject to liability under Section 18 of the Securities and Exchange Act of 1934, as amended (the “Exchange Act”), and will not be incorporated by reference into any registration statement or other document filed by the Company under the Securities Act of 1933, as amended, or the Exchange Act, unless specifically identified therein as being incorporated by reference. The furnishing of information in this Current Report, including Exhibits 99.1 and 99.2, is not intended to, and does not, constitute a determination or admission by the Company that the information in this Current Report, including Exhibits 99.1 and 99.2, is material or complete, or that investors should consider this information before making an investment decision with respect to any security of the Company or any of its affiliates.
Item 9.01. Financial Statements and Exhibits
(d) Exhibits
The following exhibits are being “furnished” as part of this Current Report:
Exhibit Number | Exhibit Description | ||||
| 99.1 | |||||
| 99.2 | |||||
| 104 | Cover Page Interactive Data File (the cover page XBRL tags are embedded within the Inline XBRL document). | ||||
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
Date: January 5, 2026
| CVR Energy, Inc. | |||||
| By: | /s/ Dane J. Neumann | ||||
| Dane J. Neumann | |||||
| Executive Vice President, Chief Financial Officer, Treasurer and Assistant Secretary | |||||
Exhibit 99.1
CVR ENERGY ANNOUNCES $75 MILLION TERM LOAN PRINCIPAL
PAYMENT AND PRELIMINARY 2026 CAPITAL SPENDING PLAN
SUGAR LAND, Texas (January 5, 2026) – CVR Energy, Inc. (NYSE: CVI, “CVR Energy” or the “Company”) today announced that certain of the Company’s subsidiaries prepaid $75 million in principal of the senior secured term loan facility (the “Term Loan”) on December 31, 2025. The total outstanding principal on the Term Loan is now approximately $165 million.
CVR Energy also announced its preliminary capital spending estimates for 2026 of $200 million to $240 million on a consolidated basis. Estimated capital expenditures for 2026 by segment are as follows:
| 2026 Estimate | ||||||||||||||||||||||||||
| Maintenance | Growth | Total | ||||||||||||||||||||||||
| (in millions) | Low | High | Low | High | Low | High | ||||||||||||||||||||
| Petroleum | $ | 80 | $ | 90 | $ | 50 | $ | 55 | $ | 130 | $ | 145 | ||||||||||||||
| Nitrogen Fertilizer | 35 | 45 | 25 | 30 | 60 | 75 | ||||||||||||||||||||
Other (1) | 10 | 15 | — | 5 | 10 | 20 | ||||||||||||||||||||
| Total | $ | 125 | $ | 150 | $ | 75 | $ | 90 | $ | 200 | $ | 240 | ||||||||||||||
(1)Capital expenditures for the Renewables Segment are expected to be minimal following the reversion of the renewable diesel unit back to hydrocarbon processing service in December 2025, and are included in “Other” for purposes of this guidance.
“We are pleased to make continued progress on our deleveraging strategy and have paid down 50 percent of the balance of the Term Loan issued in December 2024,” said Mark Pytosh, CVR Energy’s Chief Executive Officer. “We remain committed to returning our balance sheet to targeted leverage levels and our 2026 capital spending plan announced today reflects our efforts to focus capital spending in the Petroleum segment on projects that support safe, reliable operations while selectively investing in targeted growth projects.”
Forward-Looking Statements
This news release may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Statements concerning current estimates, expectations and projections about future prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under the federal securities laws. These forward-looking statements include, but are not limited to, statements regarding our deleveraging strategy, future payments on our Term Loan and other debt instruments, debt levels and targets, the nature, amounts and timing of our capital spending, investment in growth projects, timing and impacts (including on capital spending) associated with reversion of our renewable diesel unit to hydrocarbon processing service, continued safe and reliable operations, and other matters. You can generally identify forward-looking statements by our use of forward-looking terminology such as “outlook,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “explore,” “evaluate,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “seek,” “should,” “upcoming,” “before,” “future,” or “will,” or the negative thereof or other variations thereon or comparable terminology. These forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. Investors are cautioned that various factors may affect these forward-
looking statements. For additional discussion of risk factors which may affect our results, please see the risk factors and other disclosures included in our most recent Annual Report on Form 10-K, any subsequently filed Quarterly Reports on Form 10-Q and our other Securities and Exchange Commission (“SEC”) filings. These and other risks may cause our actual performance or achievements to differ materially from any future performance or achievements expressed or implied by these forward-looking statements. Given these risks and uncertainties, you are cautioned not to place undue reliance on such forward-looking statements. The forward-looking statements included in this news release are made only as of the date hereof. CVR Energy disclaims any intention or obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent required by law.
About CVR Energy, Inc.
Headquartered in Sugar Land, Texas, CVR Energy is a diversified holding company primarily engaged in the petroleum refining and marketing businesses as well as in the nitrogen fertilizer manufacturing business through its interest in CVR Partners, LP. CVR Energy subsidiaries serve as the general partner and own 37 percent of the common units of CVR Partners, LP.
For further information, please contact:
Investor Relations
Richard Roberts
(281) 207-3205
Media Relations
Brandee Stephens
(281) 207-3516
Investor Presentation January 2026
Forward-Looking Statements This presentation contains forward-looking statements (“FLS”) which are protected as FLS under the PSLRA, and which are based on management’s current expectations and beliefs, as well as a number of assumptions concerning future events. The assumptions and estimates underlying FLS are inherently uncertain and are subject to a wide variety of significant business and economic uncertainties and competitive risks that could cause actual results to differ materially from those contained in the prospective information. Accordingly, there can be no assurance CVR Energy, Inc. (together with its subsidiaries, “CVI”, “CVR Energy”, “we”, “us” or the Company”) will achieve the future results we expect or that actual results will not differ materially from expectations. Statements concerning current estimates, expectations and projections about future results, performance, prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are FLS and include, but are not limited to, statements regarding future: safe and reliable operations; compliance with regulations; ability to minimize environmental impacts and create value; economic and social impacts of donations and contributions; financial performance and forecasts; strategic value of our locations and ability to capitalize thereon; strategic priorities including identification of commercial optimization opportunities and ability to improve refining margin capture or pursue asset footprint expansion opportunities; ability to maintain a disciplined approach to capital allocation; plant capacity and reliability; access to crude oil and condensate fields with price advantages or at all; exposure to Brent-WTI; percentage ownership of CVR Partners common units and its general partner; our controlling shareholder’s intention regarding ownership of our common stock and CVR Partners common units and potential strategic transactions involving us or CVR Partners; fertilizer segment service areas; fertilizer segment feedstock diversity and optionality, products produced, costs, and utilization rates; ; investment profile; generation and return of cash; divestitures; optionality of our crude oil sourcing and/or marketing network; storage capacity; liquid volume yields and production mix, including jet fuel; use of, access to (on a contracted basis or otherwise), space on and direction of pipelines we utilize; utilization rates and turnaround and other impacts thereon; crude oil slates, capacities, optimization, and throughputs and factors impacting same; benefits of our margin capture investments; opportunities created as a result of the conversion of the RDU back to hydrocarbon processing; ability to return the RDU to renewable diesel service; ability to repurpose assets, including rail, and the benefits thereof; impact of RFS on our business including but not limited to renewable volume obligations and potential reallocation thereof; RIN pricing and availability; small refinery exemptions (SREs) or other hardship relief to WRC or others; WRC’s full or partial grant or denial of hardship relief including the impact of EPA rulings and past, current or potential challenges thereto and the impact thereof on our financial position, operations and cash flow; opportunities and conditions that could impact any decision to rail products to the West; capital allocation strategies; efforts to preserve and strengthen our balance sheet and liquidity, reduce debt, return to targeted leverage levels and preserve cash; pursuit of acquisition and investment opportunities and the benefits thereof; timing and amount of our dividends/distributions, if any; capital, maintenance, growth and turnaround spending, timing, targets and benefits; power supply outages; unplanned downtime; adverse weather events; blending and participation in renewable fuel blending economics; RIN and LCFS generation, capture, pricing, purchasing and availability; rack access; product sales outlets; quality of our refining assets; the macro environment; U.S. refining capacity; gasoline and distillate supply and demand; product inventories; crack spreads; crude oil differentials (including our exposure thereto); availability, sufficiency or impact of government credit programs, including the BTC and PTC; renewables projects; our and third party nitrogen fertilizer plant capacity, production, yields, pricing, feedstocks (including types and costs thereof), inventories, utilization rates, sales, distribution methods (including rail) and revenue; imports and exports including restrictions and actual and potential tariffs thereupon; corn and grain demand, planted acres, inventories and stocks, pricing, uses, cost, consumption, production, planting and yield, including the drivers thereof; ethanol demand; global and domestic nitrogen fertilizer market conditions, production, curtailments, supply, capacity, demand and consumption; farmer economics and cost structure; trade disputes, geopolitical impacts and global fertilizer plant disruptions on fertilizer supply and pricing; fertilizer segment service areas; ability to minimize distribution costs and maximize fertilizer net back pricing; fertilizer logistics optionality and storage; sustainability of production; feedstock diversification and optimization at our Coffeyville fertilizer facility, including the economics thereof; natural gas pricing, including impacts thereof on fertilizer production; nitrogen fertilizer application rates; harvest timing; weather and soil conditions and impacts thereof on fertilizer application and pricing; fertilizer sale prepay levels; reserve levels; distributions (if any) from our 45Q JV; EBITDA and adjusted EBITDA; forecasts including projected maintenance and growth expenditures in our segments; and other matters. Please do not put undue reliance on FLS (including forecasts and projections regarding our future performance) because actual results may vary materially from those expressed or implied as a result of various factors, including, but not limited to those set forth under “Risk Factors” in the Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and any other filings with the Securities and Exchange Commission (“SEC”) by CVR Energy, Inc. (“CVI”) or CVR Partners, LP (“UAN”). These FLS are made only as of the date hereof. Neither CVI nor UAN assume any obligation to, and they expressly disclaim any obligation to, update or revise any FLS, whether as a result of new information, future events or otherwise, except as required by law. Non-GAAP Financial Measures Certain financial information in this presentation (including EBITDA and Adjusted EBITDA) are not presentations made in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and use of such terms varies from others in the same industry. Non-GAAP financial measures should not be considered as alternatives to income from continuing operations, income from operations or any other performance measures derived in accordance with GAAP. Non-GAAP financial measures have important limitations as analytical tools, and you should not consider them in isolation or as substitutes for results as reported under GAAP. This presentation includes a reconciliation of certain non-GAAP financial measures to the most directly comparable financial measures calculated in accordance with GAAP. Market and Industry Data The market and industry data included in this presentation is based on a variety of sources, including industry publications, government publications and other published sources, information from customers, distributors, suppliers, trade and business organizations and publicly available information (including reports and other information others file with the SEC, which we did not participate in preparing and as to which we make no representation), as well as our good faith estimates, which have been derived from management’s knowledge and experience. Estimates of market size and relative positions in a market are difficult to develop and inherently uncertain. Accordingly, investors should not place undue weight on the industry and market share data presented in or discussed during this presentation. 1
Constructive Refining Macro Environment 2 U.S. Gasoline and Distillate Days of Supply Continue to Trend in Line with ’21 – ’24 Average Levels(1) Favorable Refining Macro Environment Driven by Reduced Domestic Supply and Stable Demand Trends • U.S. operable refining capacity has declined over 800,000 bpd since 2020 as refineries converted to renewable fuels production or shuttered due to poor economics. Additional closures have been announced for 2026. • Global net refining capacity additions are slowing, which creates potential for global demand growth to exceed refining capacity growth in 2026. • U.S. Energy Information Administration (“EIA”) forecasting domestic consumption of gasoline to decline 1% in 2026 while supply also declines 1%. Distillate consumption in the U.S. is forecast to increase 1% in 2026, while supply is forecast to decline 5%. • Mid-Continent (“Mid Con”) Days of Supply for gasoline continue to trend better than the U.S. average, while distillate is nearly in-line. YTD 2025 vs YTD 2024 average Days of Supply: • Gasoline: Mid Con -1% vs. U.S. +1% • Distillate: Mid Con -6% vs. U.S. -8% • Multiple refined product pipeline systems under construction or under development could provide additional access to regions outside of the Mid Con, if completed. (1) Source: EIA
Company Overview 3 Petroleum Refining ▪ Two strategically located Mid-Continent refineries close to Cushing, Oklahoma. ▪ Total nameplate crude oil capacity of 206,500; average complexity rating of 10.8. ▪ Complementary logistics assets and access to key pipelines provide a variety of advantaged crude oil supply options: 100% exposure to Brent – WTI crude differential. ▪ Historically high product yield vs. peers: 97% liquid volume yield and 91% yield of gasoline and distillate.(1) (1) Based on total throughputs; for the twelve months ended September 30, 2025. Nitrogen Fertilizer ▪ CVR Energy owns the general partner and 37% of the common units of CVR Partners, LP. ▪ Two strategically located nitrogen fertilizer facilities serving the Southern Plains and Corn Belt. ▪ Primarily engaged in the production of nitrogen fertilizers - ammonia and urea ammonium nitrate (UAN). ▪ Diverse feedstock exposure through petroleum coke (“pet coke”) and natural gas. CVR Energy (NYSE: CVI) is a diversified holding company, formed in 2006, primarily engaged in the petroleum refining and marketing industry and the fertilizer manufacturing industry through its interest in CVR Partners, LP (NYSE: UAN), a publicly traded limited partnership (“CVR Partners”). Strategic Priorities: ➢ Constant focus on the safe, reliable operations of our facilities ➢ Evaluate commercial optimization opportunities to improve margin capture in the Petroleum Segment ➢ Aggressively pursue opportunities to expand our asset footprint ➢ Maintain a disciplined approach to capital allocation
Petroleum Segment Overview 4 Competitively Positioned Mid-Con Refineries ▪ Nameplate crude oil capacity of 206,500 bpd across two refineries with an average complexity rating of 10.8. ▪ Located in Group 3 of PADD II. ▪ Significant crude oil sourcing optionality via proprietary pipeline and truck gathering systems, close proximity to major crude oil hub at Cushing, and contracted space on Keystone and Spearhead pipelines for Canadian crude oil deliveries. ▪ Multiple product sales outlets between refinery racks, OneOk and NuStar pipeline systems and racks, and the bulk product market. ▪ Rail logistics assets at both refineries provide additional product marketing opportunities outside of Group 3. ▪ New refined product pipeline capacity scheduled to come online later in 2026 to provide additional outlet from Group 3 to Denver. (1) Based on crude oil throughputs for the twelve months ended September 30, 2025. (2) Coffeyville utilization impacted by the large, planned turnaround completed in 1H 2025. (3) Based on production for the twelve months ended September 30, 2025. Nameplate Capacity (bpd) Avg. Utilization(1)(2) Gasoline Distillate Other Liquids Other Coffeyville 132,000 74% 49% 44% 4% 3% Wynnewood 74,500 91% 55% 35% 10% 0% Consolidated 206,500 80% 51% 41% 6% 2% Crude Throughput Product Slate(3)
Key Operating Statistics - Petroleum 5 (1) Based on total throughputs for the twelve months ending September 30, 2025. (2) Based on total throughputs for the twelve months ending September 30, 2025. Other includes natural gasoline, isobutane, normal butane and gas oil. (3) Based on total production for the twelve months ended September 30, 2025. Other includes pet coke, NGLs, slurry, sulfur and gas oil, and specialty products such as propylene and solvents; excludes internally produced fuels. Total Throughputs(2) ~181,000 bpd Total Production(3) ~178,000 bpd Consistent History of High Refinery Utilization Rates • Five-year average utilization of 90% including turnarounds • 1Q 2025 and 2Q 2025 impacted by the large turnaround at Coffeyville Advantaged Crude Oil and Feedstock Slate • Over 60% of crude oil throughputs sourced locally via CVR’s proprietary gathering systems • Approximately 1,300 bpd of Canadian crude oil processed at Coffeyville, remainder sold at Cushing High Conversion Refineries Leveraged to Diesel • Historically high product yield – 97% liquid volume yield and 91% yield of gasoline and distillate(1)
Focused on Capture Rate Improvements 6(1) Margin Capture = Adjusted Gross Margin per barrel / Group 3 2-1-1 Benchmark including RINs. Historical Group 3 2-1-1 and CVR Energy Margin Capture(1) ▪ Group 3 2-1-1 crack spreads improved in 2025 – FY 2025 average of $22.60/bbl vs. FY 2024 average $18.05/bbl, although prices for Renewable Identification Numbers (“RINs”) in 2025 have increased as well. ▪ CVR adjusted margin capture averaged 45% for 1Q 2025 – 3Q 2025, down slightly from FY 2024 average of 48%, primarily due to the large turnaround at Coffeyville in 1H 2025 and higher RINs prices. ▪ Currently pursuing opportunities to sustainably improve margin capture at both refineries: ▪ Optimizing crude/feedstock slates and refined product marketing to generate the highest available netbacks. ▪ Reversion of the Renewable Diesel Unit (“RDU”) at Wynnewood back to hydrocarbon processing should allow for increased crude slate flexibility, while repurposing rail assets would provide for additional product shipment optionality and feedstock security. ▪ Diligently pursue Small Refinery Exemptions (“SREs”) at Wynnewood: Margin capture would have improved by approximately 5% on average for 2021 – 2024 accounting for SREs granted in August 2025. ▪ Increasing jet fuel production at Coffeyville and pursuing more opportunities to rail product west when arbs are supportive.
Capital Allocation Strategy Prioritize Sustaining Capital Investments Return Cash to Investors When Appropriate Pursue Accretive Acquisition and Investment Opportunities Maintain Strong Balance Sheet and Liquidity Disciplined Approach to Capital Allocation Maintaining safe, reliable operations is priority #1. Focusing on debt reduction in the near-term to return to targeted leverage levels while maintaining sufficient cash balances. Aggressively pursue opportunities to profitably grow our asset footprint and improve margin capture. Dividends and distributions are quarterly determination by the Boards - debt repayment progress, cash balances and free cash flow generation are among the key criteria evaluated. 7
Capital Expenditures and Turnarounds 8Note: As of December 31, 2025. ▪ Maintenance capex estimated at $80MM to $90MM. ▪ Growth capex estimated at $50MM to $55MM. ▪ Wynnewood Alky Project accounts for a significant portion of the expected 2026 growth capex spend. ▪ Currently evaluating additional low-cost/high-return opportunities aimed at increasing margin capture. ▪ No planned turnarounds in the Petroleum Segment in 2026. ▪ 2026 turnaround spending associated with pre-spending for planned turnarounds currently scheduled at Wynnewood in 2027 and Coffeyville in 2028. ▪ Currently exploring opportunities to optimize the future turnaround schedule at Coffeyville to better balance spending and increase overall throughput volumes over the turnaround cycle. Petroleum Segment estimated 2026 Capex of $130MM - $145MM 2026 Turnaround Spending of $15 - $20MM
Recent Domestic Nitrogen Fertilizer Market Conditions 9 Domestic Corn Stocks to Use Ratios and Corn Belt Nitrogen Fertilizer Pricing Trends(1) ▪ Strong demand for nitrogen fertilizers in the U.S. combined with domestic and global nitrogen fertilizer supply issues led to elevated ammonia and UAN prices in 2025. ▪ U.S. Department of Agriculture (“USDA”) estimated 98.7 million acres of corn were planted in 2025, compared to 90.9 million acres in 2024. ▪ Yield estimates of 187 bushels of corn per acre resulting in carryout inventory estimates in-line with the ten-year average. ▪ Geopolitical issues impacted fertilizer supply throughout 2025, particularly over the summer with nitrogen fertilizer plant disruptions in Egypt, Iran and Russia all driving tightness in available supplies. ▪ Major global nitrogen capacity build cycle was largely complete by 2018, with limited new production capacity anticipated over the next few years. U.S. projects under construction are primarily targeting export markets. ▪ Preliminary estimates indicating 2026 corn plantings could be approximately 95 million acres. While this is a decline from 2025, inventory levels of nitrogen fertilizers remain tight across the system, which should be supportive of pricing through 1H 2026. (1) Sources: USDA and Green Markets
Strong Demand for Corn in the U.S. Source: USDA Economic Research Service and USDA WASDE. (1) Based on 2020 – 2024 average. 10 U.S. Domestic Corn Use Historical Corn Pricing $4.37 ▪ Corn has a variety of uses and applications, including feed grains, ethanol for fuel, and feed, seed and industrial (FSI). ▪ Feed Grains: Approximately 96% of domestic feed grains are supplied by corn. Feed grains consume approximately 39% of the annual corn crop in the United States.(1) ▪ Ethanol: Consumes approximately 36% of the annual corn crop in the United States.(1) ▪ Corn production volumes are typically driven more by yield than acres planted. ▪ Nitrogen fertilizer is crucial for corn yield and is generally low on the cost curve for farmers.
(1) Based on production for the twelve months ended September 30, 2025. (2) Coffeyville Facility carries out railcar distribution via the Union Pacific (“UP”) or Burlington Northern Santa Fe (“BNSF”) railroad lines. (3) East Dubuque Facility carries out railcar distribution via the Canadian National Railway Company. Nitrogen Fertilizer Segment Overview 11 Strategically Located Nitrogen Fertilizer Facilities ▪ Large geographic footprint serving the Southern Plains and Corn Belt regions. ▪ Well positioned to minimize distribution costs and maximize netback pricing. ▪ Rail loading rack at the Coffeyville facility provides significant logistics optionality west of the Mississippi River due to access to both UP and BNSF delivery points. ▪ Production sustainability due to storage capabilities at the plants and offsite locations. ▪ Location of the Coffeyville facility allows potential for diversification of feedstock to optimize the economics between natural gas and pet coke. Metric Coffeyville Facility East Dubuque Facility Current Ammonia / UAN Capacity 1,300 / 3,100 TPD 1,075 / 950 TPD TTM Ammonia / UAN Production Volumes(1) 2,277 / 3,603 TPD (Consolidated) Feedstock Pet Coke Natural Gas Distribution Methods Rail(2) & Truck Rail(3), Truck & Barge
Consolidated Feedstock Costs(1) (1) For the twelve months ended September 30, 2025. (2) Excludes freight and other. Key Operating Statistics – Nitrogen Fertilizer Consolidated Product Revenue(1)(2) 12 Consistent History of High Ammonia Utilization Rates • Five-year average utilization of 93% including turnarounds. • Turnarounds typically completed every 2-3 years – Coffeyville turnaround completed in 4Q 2025 and East Dubuque scheduled for 3Q 2026. Diversified Feedstock Slate • Coffeyville facility utilizes pet coke from the Coffeyville Refinery in addition to 3rd party sources, while East Dubuque uses natural gas as its primary feedstock. • Currently working on a detailed design and construction plan to allow Coffeyville to utilize natural gas and excess hydrogen from the Coffeyville Refinery as alternative feedstocks to 3rd party pet coke.
Capital Expenditures and Turnaround Expenses 13 ▪ Maintenance capex estimated at $35MM - $45MM. ▪ Growth capex estimated at $25MM - $30MM. ▪ Growth capex projects planned for 2026 primarily focused on margin improvement and debottlenecking projects at both plants. ▪ Ammonia expansion and feedstock diversification project at the Coffeyville facility, water quality upgrade projects at both facilities and diesel exhaust fluid (“DEF”) production and loadout capacity expansions. ▪ Majority of planned growth capex to be funded through reserves taken in 2023 through 2025. ▪ Coffeyville planned turnaround completed in the fourth quarter of 2025 with a total cost of approximately $16MM. ▪ East Dubuque’s next planned turnaround is currently scheduled for the third quarter of 2026. 2026 Total Capex budget of $60MM - $75MM 2026 Turnaround expense estimated at $30 - $35MM Note: As of December 31, 2025.
APPENDIX
Mission and Values Safety - We always put safety first. The protection of our employees, contractors and communities is paramount. We have an unwavering commitment to safety above all else. If it’s not safe, then we don’t do it. Environment - We care for our environment. Complying with all regulations and minimizing any environmental impact from our operations is essential. We understand our obligation to the environment and that it’s our duty to protect it. Integrity - We require high business ethics. We comply with the law and practice sound corporate governance. We only conduct business one way – the right way with integrity. Corporate Citizenship - We are proud members of the communities where we operate. We are good neighbors and know that it’s a privilege we can’t take for granted. We seek to make a positive economic and social impact through our financial donations and contributions of time, knowledge and talent of our employees to the places where we live and work. Continuous Improvement - We foster accountability under a performance-driven culture. We believe in both individual and team success. We foster accountability under a performance-driven culture that supports creative thinking, teamwork, diversity and personal development so that employees can realize their maximum potential. We use defined work practices for consistency, efficiency and to create value across the organization. Our core values are driven by our people, inform the way we do business each and every day and enhance our ability to accomplish our mission and related strategic objectives. Our mission is to be a top tier North American renewable fuels, petroleum refining, and nitrogen-based fertilizer company as measured by safe and reliable operations, superior financial performance and profitable growth. 15
16 Adjusted EBITDA represents EBITDA adjusted for certain significant noncash items and items that management believes are not attributable to or indicative of our on-going operations or that may obscure our underlying results and trends. Adjusted Refining Margin and Adjusted Renewables Margin represents Refining Margin and Renewables Margin adjusted for certain significant non- cash items and items that management believes are not attributable to or indicative of our underlying operational results of the period or that may obscure results and trends we deem useful. Direct Operating Expenses per Throughput Barrel represents direct operating expenses for the Company’s Petroleum segment divided by total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period. Direct Operating Expenses per Vegetable Oil Throughput Gallon represents direct operating expenses for the Company’s Renewables segment divided by total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period. EBITDA represents net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense. Refining Margin represents the difference between the Company’s Petroleum segment net sales and cost of materials and other. Refining Margin and Adjusted Refining Margin per Throughput Barrel represents Refining Margin and Adjusted Refining Margin divided by the total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period. Renewables Margin represents the difference between the Company’s Renewables segment net sales and cost of materials and other. Renewables Margin and Adjusted Renewables Margin per Vegetable Oil Throughput Gallon represents Renewables Margin and Adjusted Renewables Margin divided by the total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period. Note: Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document. Non-GAAP Financial Measures
Non-GAAP Financial Measures 17 (In USD Millions) CVR Energy, Inc. 2021 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Net income (loss) 74$ 644$ 878$ 45$ 40$ (105)$ (90)$ 401$ 246 Add: Interest expense and other financing costs, net of interest income 117 85 52 77 20 25 30 25 100 Add: Income tax expense (benefit) (8) 157 207 (26) (12) (49) (42) 88 (15) Add: Depreciation and amortization 279 288 298 298 74 68 78 111 331 EBITDA 462$ 1,174$ 1,435$ 394$ 122$ (61)$ (24)$ 625$ 662$ Changes in the RFS liability 63 135 (284) (89) (57) 112 89 (471) (327) Gain on marketable securities and sale of equity method investment (81) - - (24) (24) - - - (24) Unrealized loss (gain) on derivatives, net (16) 5 (32) 22 6 (3) 2 8 13 Inventory valuation impacts, unfavorable (favorable) (127) (24) 45 14 20 (24) 32 18 46 Call Option Lawsuits settlement - 79 - - - - - - - Adjusted EBITDA 301$ 1,369$ 1,164$ 317$ 67$ 24$ 99$ 180$ 370$
Non-GAAP Financial Measures 18 Petroleum Segment Refining Margin and Adjusted Refining Margin ($ in Millions) 2021 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Net sales 6,721$ 9,919$ 8,287$ 6,920$ 1,755$ 1,477$ 1,561$ 1,739$ 6,532$ Less: Cost of materials and other (6,100) (8,488) (6,629) (6,236) (1,590) (1,482) (1,526) (1,031) (5,629) Direct operating expenses (exclusive of depreciation and amortization) (369) (426) (406) (421) (101) (93) (102) (113) (409) Depreciation and amortization (197) (182) (185) (174) (41) (41) (48) (52) (182) Gross profit (loss) 55 823 1,067 89 23 (139) (115) 543 312 Add: Direct operating expenses (exclusive of depreciation and amortization) 369 426 406 421 101 93 102 113 409 Depreciation and amortization 197 182 185 174 41 41 48 52 182 Refining margin 621 1,431 1,658 684 165 (5) 35 708 903 Adjustments: Inventory valuation impacts, unfavorable (favorable) (127) (22) 32 6 12 112 89 11 224 Unrealized loss (gain) on derivatives, net (16) 3 (30) 22 6 (3) 2 8 13 Changes in the RFS liability 63 135 (284) (89) (57) (20) 31 (471) (517) Adjusted refining margin 541$ 1,547$ 1,376$ 623$ 126$ 84$ 157$ 256$ 623$ Petroleum Segment Refining Margin and Adjusted Refining Margin per Throughput Barrel ($ in Millions) 2021 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Refining margin 621$ 1,431$ 1,658$ 684$ 165$ (5)$ 35$ 708$ 903$ Dividend by: total throughput barrels 76 75 76 72 20 11 16 20 66 Refining margin per total throughput barrel 8.14$ 19.09$ 21.82$ 9.53$ 8.37$ (0.42)$ 2.21$ 35.65$ 13.68$ Adjusted refining margin 541$ 1,547$ 1,376$ 623$ 126$ 84$ 157$ 256$ 623$ Dividend by: total throughput barrels 76 75 76 72 20 11 16 20 66 Adjusted refining margin per throughput barrel 7.12$ 20.65$ 18.11$ 8.67$ 6.45$ 7.72$ 9.95$ 12.87$ 9.44$ Petroleum Segment Direct Operating Expenses per Throughput Barrel ($ in Millions) 2021 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Direct operating expenses 369$ 426$ 406$ 421 101 93 102 113 409 Divided by: total throughput (mm bbls) 76 75 76 72 20 11 16 20 66 Direct operating expenses per total throughput barrel 4.83$ 5.68$ 5.34$ 5.86$ 5.13$ 8.58$ 6.45$ 5.69$ 6.19$
Non-GAAP Financial Measures 19 Renewables Segment Renewables Margin and Adjusted Renewables Margin ($ in Millions) 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Net sales 338$ 559$ 289$ 93$ 66$ 76$ 99$ 334$ Less: Cost of materials and other (342) (537) (245) (79) (50) (71) (99) (299) Direct operating expenses (exclusive of depreciation and amortization) (24) (28) (31) (8) (6) (7) (9) (30) Depreciation and amortization (16) (20) (25) (6) (6) (6) (36) (54) Gross profit (loss) (44) (26) (12) - 4 (8) (45) (49) Add: Direct operating expenses (exclusive of depreciation and amortization) 24 28 31 8 6 7 9 30 Depreciation and amortization 16 20 25 6 6 6 36 54 Renewables margin (4) 22 44 14 16 5 - 56 Adjustments: Inventory valuation impacts, unfavorable (favorable) 7 14 7 6 (3) 1 8 12 Unrealized loss (gain) on derivatives, net 5 (2) - - - - - - Adjusted renewables margin 8$ 34$ 51$ 20$ 13$ 6$ 8$ 68$ Renewables Segment Renewables margin (4)$ 22$ 44$ 14$ 16$ 5$ -$ 56$ Dividend by: total vegetable oil throughput gallons 43 82 55 17 14 14 19 64 Renewables margin per vegetable oil throughput gallon (0.10)$ 0.27$ 0.80$ 0.79$ 1.13$ 0.38$ (0.01)$ 0.87$ Adjusted Renewables margin 8$ 34$ 51$ 20$ 13$ 6$ 8$ 68$ Dividend by: total vegetable oil throughput gallons 43 82 55 17 14 14 19 64 Adjusted Renewables margin per vegetable oil throughput gallon 0.18$ 0.41$ 0.93$ 1.16$ 0.94$ 0.44$ 0.37$ 1.06$ Renewables Segment Direct Operating Expenses per Vegetable Oil Throughput Gallon ($ in Millions) 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Direct operating expenses 24$ 28$ 31$ 8$ 6$ 7$ 9$ 30$ Divided by: total throughput (mm bbls) 43 82 55 17 14 14 19 64 Direct operating expenses per vegetable oil throughput gallon 0.55$ 0.35$ 0.57$ 0.48$ 0.48$ 0.54$ 0.45$ 0.47$ TTM3Q 20252024Renewables Margin and Adjusted Renewables Margin per Vegetable Oil Throughput Gallon ($ in Millions) 2022 2023 4Q 2024 1Q 2025 2Q 2025
Non-GAAP Financial Measures 20 (In USD Millions) CVR Partners, LP 2021 2022 2023 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 TTM Net Income (loss) 78$ 287$ 172$ 61$ 18$ 27$ 39$ 43$ 127$ Add: Interest expense and other financing costs, net of interest income 61 34 29 30 7 8 7 8 30 Add: Depreciation and amortization 74 82 80 88 25 18 21 20 84 EBITDA and Adjusted EBITDA 213$ 403$ 281$ 179$ 50$ 53$ 67$ 71$ 241$
2025 & 2026 Est. Capital Expenditures 21 (in milions) Low High Low High Low High Petroleum 82$ 87$ 34$ 38$ 116$ 125$ Renewables 3 4 1 2 4 6 Nitrogen Fertilizer 39 42 19 23 58 65 Other 1 2 1 2 2 4 Total 125$ 135$ 55$ 65$ 180$ 200$ 2025 Estimate Maintenance Growth Total (in milions) Low High Low High Low High Petroleum 80$ 90$ 50$ 55$ 130$ 145$ Nitrogen Fertilizer 35 45 25 30 60 75 Other(1) 10 15 - 5 10 20 Total 125$ 150$ 75$ 90$ 200$ 240$ 2026 Estimate Maintenance Growth Total (1) Capital expenditures for the Renewables Segment are expected to be minimal following the reversion of the renewable diesel unit back to hydrocarbon processing service and are included in ‘Other’ for purposes of this guidance.
RINs Summary 22 • CVR’s Coffeyville and Wynnewood refineries are subject to the Renewable Fuel Standards (“RFS”) implemented by the U.S. Environmental Protection Agency (the “EPA”), which requires refineries to either blend renewable fuels into their transportation fuels or purchase renewable fuel credits, knows as RINs, in lieu of blending. • Historically, Wynnewood has qualified for and received Small Refinery Exemptions (“SREs”) from the EPA, exempting it from compliance with the RFS. Refineries with capacity less than 75,000 barrels per day that would face Disproportionate Economic Harm (“DEH”) through complying with the RFS can apply for SREs, as prescribed by the RFS regulation. • CVR Energy’s obligated party subsidiary, Wynnewood Refining Company, LLC (“WRC”), has suffered DEH due to the RFS and has petitioned for SREs which would relieve it from RFS obligations. • On August 22, 2025, the EPA issued a decision document affirming the validity of its previous grants of WRC’s SREs for 2017 and 2018, granting 100% waivers for WRC’s 2019 and 2021 compliance periods, and 50% waivers for its 2020, 2022, 2023 and 2024 compliance periods. • Based on this decision, WRC reduced its balance sheet obligation related to the 2020 – 2025 compliance periods by over 420 million RINs, resulting in an obligation of 90 million RINs as of September 30, 2025. • Assuming another 50% SRE is granted for WRC’s 2025 obligation, as of September 30, 2025, approximately $100 million worth of RINs would need to be purchased by March 31, 2026, in order to satisfy both of CVR’s obligated subsidiaries’ 2024 and 2025 obligations.
CVR Energy, Inc. NYSE: CVI Icahn Enterprises L.P. & Affiliates Public CVR GP, LLC CVR Partners, LP NYSE: UAN Nitrogen Fertilizer Segment Subsidiaries Petroleum Segment Subsidiaries Public 60.6 % N-E GP Interest • Non-Economic General Partner Interest (“N-E GP Interest”) • All ownership percentages are 100% unless otherwise noted and may be indirect with intervening subsidiaries omitted for simplicity. 30.0 % 70.0 % 36.8 % JV: 45Q Entities Other Subsidiaries JV Entity: Enable South Central Pipeline, LLC 40% 50% 2.6 % Renewables Segment Subsidiaries Simplified Organizational Structure 23