CVR Energy Inc.
10/30/2025 | Press release | Distributed by Public on 10/30/2025 14:46
Quarterly Report for Quarter Ending September 30, 2025 (Form 10-Q)
Management's Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition, results of operations, and cash flows should be read in conjunction with our unaudited condensed consolidated financial statements and related notes and with the statistical information and financial data included elsewhere in this Report, as well as our Annual Report on Form 10-K for the year ended December 31, 2024 filed with the U.S. Securities and Exchange Commission (the "SEC") on February 19, 2025 (the "2024 Form 10-K"). Results of operations for the three and nine months ended September 30, 2025 and cash flows for the nine months ended September 30, 2025 are not necessarily indicative of results to be attained for any other period. See "Important Information Regarding Forward-Looking Statements." References to "CVR Energy", the "Company", "we", "us", and "our", may refer to consolidated subsidiaries of CVR Energy, including CVR Refining, LP or CVR Partners, LP, as the context may require.
Reflected in this discussion and analysis is how management views the Company's current financial condition and results of operations, along with key external variables and management's actions that may impact the Company. This discussion may contain forward-looking statements that reflect our plans, estimates and beliefs. Our actual results could differ materially from those discussed in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed below and elsewhere in this Report.
Company Overview
CVR Energy is a diversified holding company primarily engaged in the petroleum refining and marketing industry (the "Petroleum Segment"), the renewable fuels industry (the "Renewables Segment"), and the nitrogen fertilizer manufacturing industry through its interest in CVR Partners, LP, a publicly traded limited partnership (the "Nitrogen Fertilizer Segment" or "CVR Partners"). The Petroleum Segment is an "independent petroleum refiner", in that it does not have crude oil exploration or production operations, and is a marketer of high value transportation fuels primarily in the form of gasoline and diesel fuels. The Renewables Segment refines feedstocks, including soybean oil, corn oil, and other related renewable feedstocks, into renewable diesel. CVR Partners produces and markets nitrogen fertilizers primarily in the form of urea ammonium nitrate ("UAN") and ammonia.
We operate under three reportable segments: petroleum, renewables, and nitrogen fertilizer, which are referred to in this document as our "Petroleum Segment", our "Renewables Segment", and our "Nitrogen Fertilizer Segment", respectively.
Company Developments
As previously announced, on August 22, 2025, the U.S. Environmental Protection Agency (the "EPA") issued a decision document to the Company's subsidiary, Wynnewood Refining Company, LLC ("WRC"), affirming the validity of its previous grant of WRC's petitions for small refinery hardship relief under the Renewable Fuel Standard ("RFS") for WRC's 2017 and 2018 compliance periods and granting 100 percent waivers for WRC's 2019 and 2021 compliance periods and granting 50 percent waivers for its 2020, 2022, 2023 and 2024 compliance periods (the "2025 SRE Decision"). Based on this decision, WRC's obligations for the 2020 through 2024 compliance periods were reduced by more than 424 million RINs, representing approximately $488 million. Refer to Part I, Item 1, Note 12 ("Commitments and Contingencies") of this Report for further discussion.
Further, during the third quarter of 2025, the Company resolved to revert the renewable diesel unit ("RDU") at the refinery located in Wynnewood, Oklahoma (the "Wynnewood Refinery") back to hydrocarbon processing service at the next scheduled catalyst change in December 2025, considering the unfavorable economics of the renewables business and to optimize feedstock and relieve certain logistical constraints within the refining business. The Company expects to maintain the option to switch back to renewable diesel service if incentivized to do so. Refer to Part I, Item 1, Note 4 ("Long-Term Assets") of this Report for further discussion.
Strategy and Goals
The Company has adopted Mission and Core Values, which articulate the Company's expectations for how it and its employees do business each and every day.
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Mission and Core Values
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 performance and profitable growth. The foundation of how we operate is built on five core 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 the contributions of time, knowledge and talent of our employees to the places where we live and work.
•Continuous Improvement - 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.
Strategic Objectives
We have outlined the following strategic objectives to drive the accomplishment of our mission:
•Environmental, Health & Safety ("EH&S")- We aim to achieve continuous improvement in all EH&S areas through ensuring our people's commitment to environmental, health and safety comes first, the refinement of existing policies, continuous training, and enhanced monitoring procedures.
•Reliability - Our goal is to achieve industry-leading utilization rates at our facilities through safe and reliable operations. We are focusing on improvements in day-to-day plant operations, identifying alternative sources for plant inputs to reduce lost time due to third-party operational constraints, and optimizing our commercial and marketing functions to maintain plant operations at their highest level.
•Market Capture- We continuously evaluate opportunities to improve the facilities' realized pricing at the gate and reduce variable costs incurred in production to maximize our capture of market opportunities.
•Financial Discipline- We strive to be as efficient as possible by maintaining low operating costs and disciplined deployment of capital.
Industry Factors and Market Indicators
General Business Environment
Geopolitical Matters- Changes, and proposed changes, to the U.S. global trade policy, along with renewed trade tensions and related international retaliatory measures, have continued to drive volatility in global markets and create uncertainty around short- and long-term economic impacts in the U.S. and around the globe, including concerns over inflation, recession, and slowing growth. In addition, the ongoing Russia-Ukraine war and continued conflicts and tensions in the Middle East present significant geopolitical risks to global markets, with direct implications for the global oil, fertilizer, agriculture, and other industries. These factors, together with tentative and ongoing peace negotiations in the affected regions, could lead to further oil price and inventory volatility, as well as disruptions in the production and trade of fertilizer, grains, and feedstock through
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various means, such as trade restrictions and sanctions. The ultimate impacts of these conflicts and economic policy changes, or further escalation, expansion, or resolution thereof, and any associated market disruptions are difficult to predict and may affect our business, operations, cash flows, and access to capital in unforeseen ways.
Regulatory Environment- In addition to existing regulations like the RFS of the Clean Air Act, which significantly impacts our business, there have been several proposed and enacted climate-related rules and compliance requirements at federal, state, and international levels. While the Biden Administration advanced stricter Environmental Protection Agency ("EPA") motor vehicle emissions standards and the SEC's proposed climate risk disclosure rule, changes following the 2024 U.S. presidential election have shifted regulatory priorities. Under the new Administration, a combination of executive orders, regulatory rollbacks and new legislation have curtailed, delayed or restructured some of these initiatives, including the promotion of incentives to increase fossil fuel production and EPA's recent grant of Small Refinery Exemptions under existing criteria. Climate-related reporting requirements at the state level also remain under discussion, further contributing to a more uncertain regulatory landscape which may materially impact our business, operations, feedstock and compliance costs, results of operations and overall market stability.
Petroleum Segment
The earnings and cash flows of the Petroleum Segment are primarily affected by the relationship between refined product prices and the prices for crude oil and other feedstocks that are processed and blended into refined products together with the cost of refinery compliance, including the cost of compliance with RFS regulations. The cost to acquire crude oil and other feedstocks and the price for which refined products are ultimately sold depends on factors beyond the Petroleum Segment's control, including the supply of and demand for crude oil, as well as gasoline, distillate, and other refined products which, in turn, depend on, among other factors, changes in domestic and foreign economies and trade policies, driving habits, weather conditions, domestic and foreign political affairs, production levels, the availability or permissibly of imports and exports, the marketing of competitive fuels, the extent of government regulations, and the outcome of legal or regulatory proceedings. Because the Petroleum Segment applies first-in, first-out ("FIFO") accounting to value its inventory, crude oil and refined product price movements may impact margin as a result of changes in the value of its unhedged inventory. The effect of changes in crude oil prices on the Petroleum Segment's results of operations is also influenced by the rate at which the processing of refined products adjusts to reflect these changes.
The prices of crude oil and other feedstocks and refined products are also affected by other factors, such as product pipeline capacity, system inventory, local and regional market conditions, inflation, and the operating levels of other refineries. Crude oil costs and the prices of refined products have historically been subject to wide fluctuations. Widespread expansion or upgrades of third-party facilities, shutdowns or curtailments, price volatility, international political and economic developments, and other factors are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the refining industry typically experiences seasonal fluctuations in demand for refined products, such as increases in the demand for gasoline during the summer driving season and for volatile seasonal exports of diesel from the United States Gulf Coast. Specific factors impacting the Company's operations are outlined below:
Current Market Outlook
•We characterize current crack spreads as near mid-cycle levels. This is due to a combination of the refined products market being oversupplied, as refinery utilization has been above the 5-year history for most of 2025, improved fleet mileage, and reduced manufacturing activity which has led to steady gas and diesel demand. Diesel crack spreads have been elevated so far in 2025 and sustained economic growth could strengthen them further.
•Shale oil production continues to increase in certain shale oil basins, albeit at a slower pace than in prior years, including in the Anadarko Basin. Crude oil exports in the United States have sustained a 4 million bpd rate for most of the year, although recent exports have been reduced, and we believe the Petroleum Segment benefits from these exports through the Brent crude oil differential to WTI, as should all refineries in PADD II.
•Total operable refining capacity in the United States has declined by approximately 900,000 bpd on a net basis, since 2020, with the reduction of approximately 1.5 million bpd of refined product capacity offset by the addition of approximately 600,000 bpd of capacity from the completion of expansion projects at existing domestic refineries over the past few years. Globally, several new refineries have been completed in the Middle East, Asia, Mexico and Africa, although these capacity additions have been offset somewhat by additional refinery closures, and should be further impacted by nearly 1 million bpd of announced additional capacity closures in the United States and Europe expected
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by the end of 2025. Over the next few years, the pace of global capacity growth is expected to slow with few new refineries scheduled to come online, which could lead to a tightening in global refined product supply and demand balances as global demand growth is expected to continue increasing.
•Ukraine drone strikes are estimated to have reduced Russian refinery rates by 400,000 to 500,000 bpd, supporting global refined product crack spreads.
•On July 4, 2025, the One Big Beautiful Bill Act (the "OBBB") was signed into law, making significant amendments to federal tax law including the permanent extension of several provisions of the 2017 Tax Cuts and Jobs Act. These changes are expected to provide incentives that may spur U.S. GDP growth through business investments, consumer spending and industrial activity, which may increase demand for refined products and energy consumption.
•New liquid natural gas ("LNG") projects coming online and expansion of export capacity in the United States may contribute to the increase of global supply of natural gas and thus downward pressure on prices, and may also support truck fleet shifting from diesel to LNG.
•While the Chinese government has taken several steps to spur economic activity, the Chinese economy is still weighed by a weak property sector and lower domestic demand for transportation fuels. China has seen a significant increase in EV sales as well as the conversion of heavy trucks to LNG. A sustained reduction of Chinese transportation fuel demand could increase global inventories and ultimately impact the prices and margins we realize absent a corresponding decline in production or global crude oil prices.
Regulatory Environment
We continue to be impacted by significant volatility and costs associated with current and proposed laws, rules, regulations and policies, including the reinterpretation and amplification thereof, relating to the RFS, energy transition, and related matters.
•Certain of the Petroleum Segment's subsidiaries are subject to the RFS (collectively, the "obligated-party subsidiaries"), which, each year, absent exemptions or waivers, requires such obligated-party subsidiaries to blend renewable fuels with transportation fuels, purchase renewable fuel credits, known as renewable identification numbers ("RINs"), in lieu of blending, or otherwise face liability. Our cost to comply with the RFS is dependent upon a variety of factors, which include but are not limited to, the availability of ethanol and biodiesel for blending at our refineries and downstream terminals or RINs for purchase, the actions of RIN market participants including non-obligated parties, the price at which RINs can be purchased, transportation fuel and renewable diesel production levels and pricing including potential discounts thereto related to the RFS, the mix of our products, our refining margins and other factors, all of which can vary significantly from period to period, as well as certain waivers or exemptions to which we may be entitled. As of September 30, 2025 and including the impacts of the 2025 SRE Decision, we have an estimated liability of $93 million for the Petroleum Segment's obligated-party subsidiaries' compliance with the RFS for 2023 through 2025, which consists of approximately 90 million RINs, excluding open, fixed-price commitments to purchase a net 9 million RINs. The Company's open RFS position, which does not consider open commitments expected to settle in future periods, is marked-to-market each period and thus significant market volatility, as experienced in late 2023 through 2025, could impact our costs to comply with RFS (excluding the impacts of any exemptions or waivers to which the Petroleum Segment's obligated-party subsidiaries may be entitled) and has the potential to remain significant through 2025 and beyond.
•In the United States in the third quarter of 2025, approximately 11% of new-vehicle sales were EVs, an increase of approximately 2% from the third quarter of 2024. While the EPA in March 2024 finalized aggressive new motor vehicle emissions standards for light-, medium-, and heavy-duty vehicles for model year 2027 and beyond and the National Highway Traffic Safety Administration ("NHTSA") of the Department of Transportation ("DOT") in June 2024 finalized new and aggressive Corporate Average Fuel Economy standards to increase passenger car and light truck fuel economy, the new Administration has rolled back some of these aggressive actions, as indicated in the March 2025 announcement from the EPA Administrator that it will reconsider the standards as well as the June 2025 interpretative rule issued by NHTSA titled "Resetting the Corporate Average Fuel Economy Program" together with certain provisions of the OBBB which includes provisions that rescind or delay various aspects of these standards. In July 2025, the EPA Administrator signed a proposed rule to repeal all greenhouse gas emission standards for light-, medium-, and heavy-duty vehicles and engines.
•During 2024, multiple bills were introduced in Congress that would extend the Biodiesel Blenders' Tax Credit ("BTC"). Extensions of this tax incentive have been passed by Congress and signed into law close to, and even after, expiration dates in the past. However, we believe provisions of the Inflation Reduction Act that created the Clean Fuel
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Production Credit ("PTC") and provisions of the OBBB, which was signed into law on July 4, 2025 and modifies and extends the PTC, likely signals the end of the BTC. If the BTC is not renewed, RINs prices could be further impacted.
•Uncertainty in the regulatory environment continues as President Trump adjusts the U.S. global trade policy. Crude oil and refined product import and export volumes could be negatively impacted by these changes.
Company Initiatives
•The Company has undertaken a project to replace the hydrofluoric acid catalyst alkylation unit at the refinery in Wynnewood, Oklahoma (the "Wynnewood Refinery") with a fixed bed catalyst system, which should expand the alkylation unit by approximately 2,500 bpd, increase product capture by reducing propylene production/sales and increasing production of premium gasoline, and eliminate hydrofluoric acid inventory onsite. The capital investment is estimated at $136 million, and the unit is expected to become operational later in 2027.
•In April 2024, the Board approved a distillate yield improvement project at the Wynnewood Refinery to modify one of the vacuum towers, which may increase distillate production at the refinery by up to approximately 2,400 bpd. With the decision to revert the RDU back to hydrocarbon processing services, the capital requirement is lowered from previous guidance to $3 million. The Company has implemented the first phase of a similar project at the refinery in Coffeyville, Kansas (the "Coffeyville Refinery") which could increase production of distillate up to 1,300 bpd. The Company is also studying a second phase which could increase production of distillate by up to 2,600 bpd.
•In connection with our settlement with the EPA on certain environmental issues at the Coffeyville Refinery, the Company is in the process of installing a flare gas recovery system at a cost of approximately $50 million, which is expected to be operational in late 2026.
•The Company started production and sales of jet fuel from its Coffeyville Refinery in the third quarter of 2025. While we expect production and sales to be lower at the outset, they could gradually increase over time to as much as 9,000 bpd and if achieved, could reduce RIN exposure by as much as 22 million RINs per year.
Market Indicators
NYMEX WTI crude oil is an industry wide benchmark that is utilized in the market pricing of a barrel of crude oil. The pricing differences between other crude oils and WTI, known as differentials, show how the market for other crude oils, such as WCS, White Cliffs ("Condensate"), Brent Crude ("Brent"), and Midland WTI ("Midland") are trending. Due to geopolitical events, such as the Russia-Ukraine war and the conflict in the Middle East, and, in each case, actions taken by governments and others in response thereto, refined product prices have experienced extreme volatility. As a result of the current environment, refining margins have been and will likely continue to be volatile.
We utilize NYMEX and Group 3 crack spreads as a performance benchmark and a comparison with other industry participants. These crack spreads are a measure of the difference between market prices for crude oil and refined products and are a commonly used proxy within the industry to estimate or identify trends in refining margins. Crack spreads can fluctuate significantly over time as a result of market conditions and supply and demand balances. The NYMEX 2-1-1 crack spread is calculated using two barrels of WTI producing one barrel of NYMEX RBOB Gasoline ("RBOB") and one barrel of NYMEX NY Harbor ULSD ("HO"). The Group 3 2-1-1 crack spread is calculated using two barrels of WTI crude oil producing one barrel of Group 3 sub-octane gasoline and one barrel of Group 3 ultra-low sulfur diesel.
NYMEX 2-1-1 crack spreads and Group 3 2-1-1 crack spreads both increased during the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024. The NYMEX 2-1-1 crack spread averaged $25.62 per barrel during the nine months ended September 30, 2025 compared to $25.54 per barrel in the nine months ended September 30, 2024. The Group 3 2-1-1 crack spread averaged $22.62 per barrel during the nine months ended September 30, 2025 compared to $19.25 per barrel during the nine months ended September 30, 2024.
Average monthly prices for RINs on a blended barrel basis (calculated using applicable renewable volume obligation ("RVO") percentages) increased 64.42% during the third quarter of 2025 compared to the same period of 2024. RINs approximated $6.33 per barrel during the third quarter of 2025 compared to $3.85 per barrel during the third quarter of 2024.
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The charts below are presented, on a per barrel basis, by month through September 30, 2025:
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Crude Oil Differentials against WTI (1)(2)
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NYMEX Crack Spreads (2)
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PADD II Group 3 Product Crack
Spread and RIN Pricing (2)(3) ($/bbl)
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Group 3 Product Differential against NYMEX
Products (1)(2) ($/bbl)
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(1)The change over time in NYMEX - WTI, as reflected in the charts above, is illustrated below:
| (in $/bbl) | Average 2023 | Average December 2023 | Average 2024 | Average December 2024 | Average 2025 | Average September 2025 | |||||||||||||||||||||||||||||
| WTI | $ | 77.57 | $ | 72.12 | $ | 75.77 | $ | 69.70 | $ | 66.63 | $ | 63.53 | |||||||||||||||||||||||
(2)Information used within these charts was obtained from reputable market sources, including the New York Mercantile Exchange ("NYMEX"), Intercontinental Exchange, and Argus Media, among others.
(3)PADD II is the Midwest Petroleum Area for Defense District ("PADD"), which includes Illinois, Indiana, Iowa, Kansas, Kentucky, Michigan, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Tennessee and Wisconsin.
Renewables Segment
The earnings and cash flows of the Renewables Segment are primarily affected by the relationship between renewable fuel prices, the prices for vegetable oils and other feedstocks that are processed and blended into renewable fuels, as well as the prices of various credits generated by the production of renewable fuels together with the cost of operating the renewable diesel unit, including the pre-treatment unit. The cost to acquire vegetable oils and other feedstocks and the price for which renewable fuels are ultimately sold depend on factors beyond the Renewables Segment's control, including the supply of and demand for
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vegetable oil and other feedstocks, as well as renewable diesel and other renewable fuels which, in turn, depend on, among other factors, changes in domestic and foreign economies and trade policies, driving habits, weather conditions, domestic and foreign political affairs, production levels, the availability or permissibly of imports and exports, the marketing of competitive fuels, and the extent of government regulations. Similar to the Petroleum Segment, the Renewables Segment applies FIFO accounting to value its inventory, and product price movements may thus impact margin as a result of changes in the value of its unhedged inventory. The effect of changes in product prices on the Renewables Segment's results of operations is partially influenced by the rate at which the processing of renewable fuels adjusts to reflect these changes.
The prices of vegetable oils and other feedstocks and renewable fuels are also affected by other factors, such as soybean crush capacity, system inventory, local and regional market conditions, inflation, and the operating levels of other facilities. Vegetable oil costs and the prices of renewable fuels have historically been subject to wide fluctuations. Widespread expansion or upgrades of third-party facilities, price volatility, international political and economic developments, and other factors are likely to continue to play an important role in renewable fuel industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Specific factors impacting the Company's operations are outlined below:
Current Market Outlook
•The near-term outlook for the renewables market is likely to be heavily influenced by U.S. government policies, particularly those related to the PTC, which is awaiting formal IRS rule making. On July 4, 2025, the OBBB was signed into law which has changed several elements of the PTC including the removal of land use provisions for the soybean oil carbon intensity ("CI") calculation. The legislation also included an import ban on certain foreign feedstocks used in renewable fuel production, which may impact supply chain dynamics and feedstock availability. Pending further clarification or guidance on the PTC, we continue to not recognize any PTC benefit.
•The $1 per gallon BTC expired on December 31, 2024, which caused renewable diesel and biodiesel blend rates and imports to fall significantly. With the loss of the BTC, there has been additional volatility in pricing for renewable fuel feedstocks, as well as in prices of other credits generated by renewable fuels production, particularly RINs prices and Low Carbon Fuel Standard ("LCFS") credit prices. The combination of the above factors should continue to support RIN prices.
•In June 2025, the EPA proposed the 2026 and 2027 biomass-based diesel volume at 7.12 and 7.50 billion RINs ("D4"), respectively, which is a significant increase over the 2025 volume of 5.36 billion RINs, while holding the ethanol conventional biofuel volume at 15 billion RINs. In July 2025, the EPA's partial waiver of the 2024 cellulosic biofuel volume requirement was published in the Federal Register, making the 2024 RFS compliance reporting deadline for all obligated parties December 1, 2025.
•After a substantial build-out of renewable diesel production capacity in the United States over the past four years, where capacity increased from less than 900 million gallons per year in January 2021 to over 4.7 billion gallons per year in July 2025, further renewable diesel production capacity expansion is expected to slow considerably due to the uncertainties around U.S. government policies and support of renewables businesses.
•In November 2024, the California Air Resources Board ("CARB") approved material updates to the LCFS, which were finalized in June 2025 and became effective July 1, 2025. These revisions include enhanced carbon intensity reduction targets and feedstock limits and should result in higher credits.
Regulatory Environment
•Profitability in the Renewables Segment is highly dependent on the prices of government grants, particularly RINs prices, LCFS credit prices, and tax credits. RINs prices are mainly influenced by supply and demand dynamics, with demand being heavily impacted by the annual RVO levels established by the EPA and legal and regulatory actions. Current market prices for renewable feedstocks are significantly higher than the prices for renewable fuels and, without sufficient government support to stabilize prices for credits generated by renewable fuels production, many renewable fuel producers may not be able to generate profits.
Company Initiatives
•The renewable diesel unit at the Wynnewood Refinery has the flexibility to be reverted back to hydrocarbon processing service primarily through a catalyst change, depending on market conditions, such as renewable diesel margins, governmental regulations, contractual obligations and other factors. The Company has resolved to revert the RDU back to hydrocarbon processing service at the next scheduled catalyst change in December 2025, considering the
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unfavorable economics of the renewables business and to optimize feedstock and relieve certain logistical constraints within the refining business. The Company expects to maintain the option to switch back to renewable diesel service if incentivized to do so.
Market Indicators
Chicago Board of Trade ("CBOT") soybean oil is an industry wide benchmark that is utilized in the pricing of renewable fuel feedstocks. The pricing differences between CBOT soybean oil and other renewable feedstocks such as distiller's corn oil, used cooking oil and animal fats is typically driven by the CI score related to each feedstock along, with overall supply and demand in the market for various feedstocks. Feedstock CI scores play a significant role in the generation of LCFS credits, where lower CI score feedstocks generate higher credit values than higher CI score feedstocks. The PTC would also be calculated based on CI scores, with lower CI scores generating higher credit values.
Approximately 59% of combined biodiesel and renewable diesel production in 2024 was produced from vegetable oils, with animal fats comprising the remaining 41%. Soybean oil comprised approximately 59% of the vegetable oil used as a feedstock, making it one of the primary feedstock pricing benchmarks in the renewables market. As a performance benchmark and a comparison with other industry participants, we utilize the heating oil-bean oil ("HOBO") spread and a Benchmark Renewable Diesel Margin, as defined in the chart below, that incorporates the HOBO spread along with RINs, LCFS credits, and BTCs generated by renewable diesel production.
The average quarterly HOBO spread deteriorated to $(1.28) per gallon during the nine months ended September 30, 2025 compared to $(0.88) per gallon during the nine months ended September 30, 2024, primarily as a result of lower ULSD prices and higher soybean oil prices in the current period compared to the prior period. The Benchmark Renewable Diesel Margin declined to $1.04 per gallon during the nine months ended September 30, 2025 compared to $1.79 per gallon during the nine months ended September 30, 2024, primarily due to the expiration of the BTC and the decline in the HOBO spread, partially offset by increases in prices for RINs and LCFS credits.
Average monthly prices for D4 RINs increased 87% during the third quarter of 2025 compared to the same period of 2024, while LCFS credit prices remained steady during the third quarter of 2025compared to the same period of 2024.
The tables below are presented by month through September 30, 2025:
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Benchmark Renewable Diesel Margins (1) (2) (3)
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LCFS Credit Price and D4 RIN Market Pricing (1)
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Soybean Oil and LA/SF CARB Market Pricing (1)
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(1)Information used within these charts was obtained from reputable market sources, including the New York Mercantile Exchange ("NYMEX"), CBOT, and Argus Media, among others.
(2)Renewable Diesel Indicator Margin calculated as follows:
(OPIS CARB ULSD + (D4 RIN * 1.7x) + BTC + LCFS Credit(65CI) + CAR + LCFS Fee) - (CBOT Soybean Oil * 7.6 lbs/gal).
(3)HOBO spread represents the Heating Oil - Bean Oil Spread and is calculated as CARB ULSD price per gallon less CBOT Soybean Oil price per gallon.
Nitrogen Fertilizer Segment
Within the Nitrogen Fertilizer Segment, earnings and cash flows from operations are primarily affected by the relationship between nitrogen fertilizer product prices, utilization, and operating costs and expenses, including pet coke and natural gas feedstock costs.
The price at which nitrogen fertilizer products are ultimately sold depends on numerous factors, including the global supply and demand for nitrogen fertilizer products which, in turn, depends on world grain demand and production levels, changes in world population, the cost and availability of fertilizer transportation infrastructure, weather conditions, the availability of imports, the availability and price of feedstocks to produce nitrogen fertilizer, and the extent of government intervention in agriculture markets, among other factors. These factors can impact, among other things, the level of inventories in the markets, resulting in price and product margin volatility. Moreover, the industry typically experiences seasonal fluctuations in demand for nitrogen fertilizer products.
Certain governmental regulations and incentives associated with the automobile transportation and agricultural industries, including those related to corn-based ethanol and vegetable oil-based biodiesel, renewable diesel, and sustainable aviation fuel production and consumption, can impact, and have directly impacted, our business. In June 2023, the EPA announced the renewable volume obligations for 2023, 2024, and 2025 limiting the conventional biofuel volume to 15 billion gallons. In June 2025, the EPA proposed to maintain the conventional biofuel volume at 15 billion gallons for 2026 and 2027. In August 2025, the EPA addressed a backlog of 175 small refinery exemption petitions covering compliance years 2016 to 2024, granting full or partial exemptions to 140 refineries. The EPA is considering reallocating the exempted gallons from 2023 to present to other refiners, which, if implemented, would be included in the final conventional biofuel volume for 2026 and 2027. While a low reallocation requirement could depress demand for corn and soybeans used in fuels blending, we believe that the government will seek ways to mitigate the potential impact on farmers and support continued planting activities in the future. In addition, provisions of the Section 45Z Clean Fuel Production Credit exclude imports of renewable fuels and imported feedstocks used to produce renewable fuels in the United States, which we expect to support demand for domestic corn and soybean oil
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feedstocks. In 2024, corn used in ethanol production consumed approximately 37% of the annual production of the U.S. corn crop.
Market Indicators
While there is risk of shorter-term volatility given the inherent nature of the commodity cycle and governmental and geopolitical risks, the Company believes the long-term fundamentals for the U.S. nitrogen fertilizer industry remain intact. The Nitrogen Fertilizer Segment views the anticipated combination of (i) increasing global population, (ii) decreasing arable land per capita, (iii) continued evolution to more protein-based diets in developing countries, (iv) sustained use of corn and soybeans as feedstock for the domestic production of ethanol and other renewable fuels, and (v) positioning at the lower end of the global cost curve should provide a solid foundation for nitrogen fertilizer producers in the United States over the longer term.
Corn and soybeans are two major crops planted by farmers in North America. Corn crops result in the depletion of the amount of nitrogen within the soil in which it is grown, which in turn, results in the need for this nutrient to be replenished after each growing cycle. Unlike corn, soybeans are able to obtain most of their own nitrogen through a process known as "N fixation". As such, upon harvesting of soybeans, the soil retains a certain amount of nitrogen which results in lower demand for nitrogen fertilizer for the following corn planting cycle. Due to these factors, farmers generally operate a balanced corn-soybean rotational planting cycle as shown by the chart presented below.
The relationship between the total acres planted for both corn and soybeans has a direct impact on the overall demand for nitrogen products, as the market and demand for nitrogen increases with increased corn acres and decreases with increased soybean acres. Additionally, an estimated 16 billion pounds of soybean oil is expected to be used in producing cleaner renewable fuels in marketing year 2025/2026.
On September 25, 2025, the United States Department of Agriculture ("USDA") and the Department of Justice ("DOJ") antitrust division signed a memorandum of understanding to conduct an investigation into anti-competitive practices among suppliers of agricultural inputs, including fertilizers, seeds, and crop protection products. In addition, actual and potential tariffs imposed by the U.S. on imports of nitrogen fertilizers have been one of the factors that has caused the price of fertilizers to rise in the U.S. However, retaliatory trade actions by other countries, particularly in corn and soybeans, have been a factor in lowering grain prices and negatively impacted farmer economics.
The USDA estimates that in spring 2025 farmers planted 99 million corn acres, representing an increase of 9% compared to 91 million corn acres in 2024. Planted soybean acres are estimated to be 81 million, representing a decrease of 7% compared to 87 million soybean acres in 2024. The combined estimated corn and soybean planted acres of 180 million represents a slight increase compared to the acreage planted in 2024. Due to lower input costs in 2025 for corn planting and the relative grain prices of corn versus soybeans, economics favored planting corn compared to soybeans in 2025. Inventory levels of corn and soybeans are expected to be higher in 2026 but supportive of grain prices through the fall 2025 harvest.
Ethanol is blended with gasoline to meet RFS requirements and for its octane value. Since 2010, corn used in ethanol production has historically consumed approximately 38% of the annual production of the U.S. corn crop, so demand for corn generally rises and falls with ethanol demand. The EPA's recently proposed renewable volume requirements for 2026 and 2027 include increased volume requirements for biomass-based diesel and advanced biofuel, which are expected to be supportive of grain demand and prices. The chart below shows the production volumes of fuel ethanol in the U.S.
September 30, 2025 | 37
|
U.S. Plant Production of Fuel Ethanol (1)
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Corn and Soybean Planted Acres (2)
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(1)Information used within this chart was obtained from the U.S. Energy Information Administration ("EIA") through September 30, 2025.
(2)Information used within this chart was obtained from the USDA, National Agricultural Statistics Services as of September 30, 2025.
Weather continues to be a critical variable for crop production. Despite high planted acres and above trendline yields per acre for corn in the United States, global inventory levels for corn and soybeans remain near their historical 10-year averages and prices have remained moderated through summer 2025. Demand for nitrogen fertilizer, as well as other crop inputs, was strong for the spring 2025 planting season, primarily due to elevated grain prices and favorable weather conditions for planting.
While we expect natural gas prices might remain below the elevated levels experienced in 2022 in the near term, we believe the structural shortage of natural gas in Europe will continue to be a source of volatility through at least 2026. Pet coke prices had been elevated since 2021 due to higher oil prices compared to historical levels, but as oil prices have declined, third-party pet coke prices declined in 2024, have fallen further in 2025, and are expected to continue to fall into 2026.
CVR Partners Initiatives
Based on recently completed engineering studies the facility in Coffeyville, Kansas (the "Coffeyville Fertilizer Facility") could utilize natural gas as an optional feedstock to pet coke for the production of nitrogen fertilizer, subject to certain modifications. In addition, CVR Partners could import larger than historical quantities of hydrogen directly from the Coffeyville Refinery and increase the nameplate ammonia production of the Coffeyville Fertilizer Facility. The initial stages of the combined project have been approved by the board of directors of CVR Partners' general partner (the "UAN GP Board"), subject to engineering and final cost estimates. CVR Partners has begun detailed engineering and ordering long lead-time equipment. This project will make the Coffeyville Fertilizer Facility the only nitrogen fertilizer facility in the United States with dual feedstock flexibility.
Over the past two years, CVR Partners has reserved funds for a series of debottlenecking projects that are intended to improve reliability and ultimately facilitate potential additions to production rates at both of its fertilizer facilities. During 2025, CVR Partners has been executing projects focused on water and electrical reliability at its fertilizer facilities, along with expansions of diesel exhaust fluid production and loadout capabilities, among other projects. In addition, during the planned turnaround at the Coffeyville Fertilizer Facility, which is currently underway, CVR Partners is nearing completion on the installation of a nitrous oxide abatement unit. After installation, CVR Partners will have nitrous oxide abatement units on all four of its nitric acid plants. The funds needed in 2025 for these projects have come and are expected to come from the reserves taken over the past two years.
September 30, 2025 | 38
The charts below show relevant market indicators for the Nitrogen Fertilizer Segment by month through September 30, 2025:
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Ammonia and UAN Market Pricing (1)
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Natural Gas Market Pricing (1)
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Pet Coke Market Pricing (1)
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(1)Information used within these charts was obtained from various third-party sources, including Green Markets (a Bloomberg Company), Pace Petroleum Coke Quarterly, and the EIA, amongst others.
Results of Operations
Effective beginning with the 2024 Form 10-K, the Company has revised its reportable segments to reflect the Renewables reportable segment, which includes the operations of the RDU and renewable feedstock pretreater at the Wynnewood Refinery.
September 30, 2025 | 39
Consolidated
Our consolidated results of operations include certain unallocated corporate activities and the elimination of intercompany transactions and, therefore, do not equal the sum of the operating results of the Petroleum, Renewables, and Nitrogen Fertilizer Segments.
Consolidated Financial Highlights (Three and Nine Months Ended September 30, 2025 versus September 30, 2024)
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Operating Income (Loss)
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Net Income (Loss) Attributable to CVR
Energy Stockholders
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Earnings (Loss) per Share
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EBITDA (1)
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(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measures shown above.
Three and Nine Months Ended September 30, 2025 versus September 30, 2024 (Consolidated)
Overview - For the three months ended September 30, 2025, the Company's operating income and net income were $512 million and $401 million, respectively, compared to operating loss and net loss of $113 million and $122 million, respectively, for the three months ended September 30, 2024. For the nine months ended September 30, 2025, the Company's operating income and net income were $277 million and $206 million, respectively, compared to operating loss and net loss of $37 million and $5 million, respectively, for the nine months ended September 30, 2024. Refer to our discussion of each segment's results of operations below for further information.
September 30, 2025 | 40
Income Tax Expense (Benefit)- Income tax expense for the three months ended September 30, 2025 was $88 million, or 17.9% of income before income tax. Income tax benefit for the nine months ended September 30, 2025 was $3 million, or (1.6)% of income before income tax. Income tax benefit for the three and nine months ended September 30, 2024 was $6 million and $14 million, or 4.6% and 155.0% of loss before income tax, respectively. The changes in income tax expense (benefit) were primarily due to an increase in overall pretax earnings. In addition, the change in the effective tax rate from the three and nine months ended September 30, 2024 to the three and nine months ended September 30, 2025 was primarily caused by changes in pretax earnings attributable to noncontrolling interests and the impact of federal and state tax credits and incentives relative to overall pretax earnings.
Petroleum Segment
The Petroleum Segment utilizes certain inputs within its refining operations. These inputs include crude oil, butanes, natural gasoline, ethanol, and biodiesel (these are also known as "throughputs").
Refining Throughput and Production Data by Refinery
| Throughput Data |
Three Months Ended September 30, |
Nine Months Ended September 30, |
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| (in bpd) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Coffeyville | |||||||||||||||||||||||
| Gathered crude | 60,376 | 70,657 | 48,821 | 73,477 | |||||||||||||||||||
| Other domestic | 67,400 | 35,111 | 37,863 | 36,549 | |||||||||||||||||||
| Canadian | - | 6,243 | 405 | 8,423 | |||||||||||||||||||
| Condensate | 3,110 | - | 1,048 | 4,244 | |||||||||||||||||||
| Other feedstocks and blendstocks | 11,083 | 11,691 | 8,449 | 11,678 | |||||||||||||||||||
| Wynnewood | |||||||||||||||||||||||
| Gathered crude | 54,495 | 51,821 | 56,114 | 43,055 | |||||||||||||||||||
| Other domestic | 7,079 | 1,504 | 3,106 | 1,309 | |||||||||||||||||||
| Condensate | 6,959 | 9,663 | 8,681 | 8,634 | |||||||||||||||||||
| Other feedstocks and blendstocks | 5,466 | 2,604 | 5,361 | 3,058 | |||||||||||||||||||
| Total throughput | 215,968 | 189,294 | 169,848 | 190,427 | |||||||||||||||||||
September 30, 2025 | 41
| Production Data |
Three Months Ended September 30, |
Nine Months Ended September 30, |
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| (in bpd) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Coffeyville | |||||||||||||||||||||||
| Gasoline | 69,660 | 62,031 | 46,493 | 68,732 | |||||||||||||||||||
| Distillate | 63,040 | 52,030 | 43,552 | 55,237 | |||||||||||||||||||
| Other liquid products | 5,450 | 5,169 | 3,780 | 5,578 | |||||||||||||||||||
| Solids | 4,390 | 4,734 | 3,152 | 4,901 | |||||||||||||||||||
| Wynnewood | |||||||||||||||||||||||
| Gasoline | 36,292 | 34,539 | 37,550 | 30,746 | |||||||||||||||||||
| Distillate | 25,350 | 23,902 | 24,649 | 19,722 | |||||||||||||||||||
| Other liquid products | 9,897 | 5,874 | 7,758 | 4,600 | |||||||||||||||||||
| Solids | 9 | 11 | 10 | 8 | |||||||||||||||||||
| Total production | 214,088 | 188,290 | 166,944 | 189,524 | |||||||||||||||||||
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Crude utilization (1)
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96.6 | % | 84.7 | % | 75.6 | % | 85.1 | % | |||||||||||||||
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Light product yield (as % of crude throughput) (2)
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97.5 | % | 98.6 | % | 97.6 | % | 99.3 | % | |||||||||||||||
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Liquid volume yield (as % of total throughput) (3)
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97.1 | % | 97.0 | % | 96.4 | % | 96.9 | % | |||||||||||||||
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Distillate yield (as % of crude throughput) (4)
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44.3 | % | 43.4 | % | 43.7 | % | 42.7 | % | |||||||||||||||
(1)Total Gathered crude, Other domestic, Canadian, and Condensate throughput (collectively, "Total Crude Throughput") divided by consolidated crude oil throughput capacity of 206,500 bpd.
(2)Total Gasoline and Distillate divided by Total Crude Throughput.
(3)Total Gasoline, Distillate, and Other liquid products divided by total throughput.
(4)Total Distillate divided by Total Crude Throughput.
Petroleum Segment Financial Highlights (Three and Nine Months Ended September 30, 2025 versus September 30, 2024)
Overview -For the three months ended September 30, 2025, the Petroleum Segment's operating income and net income were $518 million and $520 million, respectively, compared to an operating loss and net loss of $119 million and $110 million, respectively, for the three months ended September 30, 2024. These improvements were primarily due to favorable RVO adjustments to reflect the 2025 SRE Decision, increases in gasoline and distillate crack spreads, and higher throughput volumes due to minor unplanned outages in the prior year period, partially offset by higher repairs and maintenance, natural gas and electricity, and personnel expenses in the current period. For the nine months ended September 30, 2025, the Petroleum Segment's operating income and net income were $224 million and $223 million, respectively, compared to operating income and net income of $9 million and $35 million, respectively, for the nine months ended September 30, 2024. Similarly, these improvements were primarily due to favorable RVO adjustments to reflect the 2025 SRE Decision, increases in gasoline and distillate crack spreads, and elevated repairs and maintenance expenses in the prior year period resulting from the fire at the Wynnewood Refinery during severe weather (the "Wynnewood Fire"), partially offset by lower throughput as a result of the Coffeyville Refinery's major turnaround which began in the first quarter of 2025 and was completed in April 2025 (the"2025 Turnaround"), and an increase in share-based compensation as a result of an increase in the market price of CVR Energy's common shares in the current year period and a decrease in the market price of CVR Energy's common shares in the prior year period.
The Company continues to accrue WRC's 2025 RFS obligation at 100% of the required amount, as no waiver has yet been granted for that compliance year. Refer to "Liquidity and Capital Resources" for additional discussion of the 2025 SRE application, potential future impacts on RFS obligations, and related effects on liquidity and capital resources.
September 30, 2025 | 42
| Petroleum Net Sales |
Petroleum Operating Income
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Petroleum Net Income (Loss)
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Petroleum EBITDA (1)
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(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measures shown above.
Net Sales- For the three and nine months ended September 30, 2025, net sales for the Petroleum Segment was $1.7 billion and $4.8 billion, respectively, compared to $1.6 billion and $5.2 billion for the three and nine months ended September 30, 2024, respectively. The increase for the three months ended September 30, 2025 was primarily due to higher sales volumes as a result of increased throughput volumes combined with higher distillate prices in the current year period, offset by lower gasoline prices in the current year period. The decrease for the nine months ended September 30, 2025 was primarily driven by lower throughput volumes as a result of the 2025 Turnaround combined with lower gasoline and distillate prices.
September 30, 2025 | 43
|
Q3 Petroleum Refining Margin (1)
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YTD Petroleum Refining Margin (1)
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(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measures shown above.
Refining Margin - For the three months ended September 30, 2025, refining margin was $708 million, or $35.65 per throughput barrel, compared to $44 million, or $2.53 per throughput barrel, for the three months ended September 30, 2024. The primary factors contributing to the $664 million increase in refining margin were:
•Favorable RFS related impacts of $473 million, which includes favorable adjustments to reflect the 2025 SRE Decision of $488 million partially offset by an unfavorable RINs revaluation of $15 million;
•An increase in the Group 3 2-1-1 crack spread of $6.58 per barrel, driven by an improvement in distillate and gasoline crack spreads primarily due to lower inventory levels and improving demand trends in the current year; and
•Unfavorable inventory valuation impacts of $11 million for the three months ended September 30, 2025 compared to $31 million for the three months ended September 30, 2024, primarily due to smaller decreases in crude oil and gasoline prices in the current period compared to the third quarter of 2024, partially offset by rising distillate prices in the current year compared to falling distillate prices in the third quarter of 2024.
Factors partially offsetting the increase in refining margin were:
•An increase in the RVO weighted cost of RFS compliance of $2.48 per barrel primarily due to an increase in the price of Ethanol RINs.
For the nine months ended September 30, 2025, refining margin was $738 million, or $15.93 per throughput barrel, compared to $520 million, or $9.96 per throughput barrel, for the nine months ended September 30, 2024. The primary factors contributing to the $218 million increase in refining margin were:
•Favorable in RFS related impacts of $164 million, which includes favorable adjustments to reflect the 2025 SRE Decision of $488 million partially offset by an unfavorable RINs revaluation of $324 million due to higher RINs pricing combined with a net short position in the 2025 period as compared to the 2024 period;
•An increase in the Group 3 2-1-1 crack spread of $3.37 per barrel, driven by an improvement in distillate and gasoline crack spreads primarily due to lower inventory levels and improving demand trends in the current year; and
•Favorable derivative impacts of $13 million in the 2025 period as compared to the 2024 period resulting primarily from realized gains on Canadian crude oil positions in the current year.
Factors partially offsetting the increase in refining margin were:
•Unfavorable sales volume impacts as a result of the 2025 Turnaround; and
•Unfavorable inventory valuation impacts of $21 million for the nine months ended September 30, 2025 compared to favorable inventory valuation impacts of $8 million for the nine months ended September 30, 2024, primarily due to a larger decrease in crude oil prices and smaller increase in gasoline prices in the current year as compared to 2024.
September 30, 2025 | 44
|
Q3 Petroleum Direct Operating Expenses (1)
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YTD Petroleum Direct Operating Expenses (1)
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(1)Exclusive of depreciation and amortization expense.
Direct Operating Expenses (Exclusive of Depreciation and Amortization) - For the three and nine months ended September 30, 2025, direct operating expenses (exclusive of depreciation and amortization) were $113 million and $306 million, respectively, compared to $100 million and $320 million for the three and nine months ended September 30, 2024, respectively. The increase for the three months ended September 30, 2025 was primarily due to increased current period repairs and maintenance expenses, personnel costs, and natural gas and electricity costs as a result of higher prices, partially offset by lower insurance and environmental expenses and insurance claims received in the prior year period related to the Wynnewood Fire. The decrease for the nine months ended September 30, 2025 was primarily attributable to elevated repairs and maintenance expenses incurred during the prior-year period related to the Wynnewood Fire, net of insurance claims, combined with lower insurance expenses in the current period, partially offset by increased personnel costs and higher lease expense in the current period. On a total throughput barrel basis, direct operating expenses decreased to $5.69 per barrel for the three months ended September 30, 2025, from $5.72 for the three months ended September 30, 2024, and increased to $6.62 per barrel for the nine months ended September 30, 2025, from $6.14 per barrel for the nine months ended September 30, 2024. The increase for the nine months ended September 30, 2025 was primarily due to decreased throughput volumes in the current period resulting from the 2025 Turnaround, partially offset by reduced direct operating expenses in the current period and minor unplanned outages reducing throughput in the prior year period.
September 30, 2025 | 45
| Petroleum Depreciation and Amortization Expense |
Petroleum Selling, General, and Administrative Expenses |
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Depreciation and Amortization Expense- For the three and nine months ended September 30, 2025, depreciation and amortization expense was $52 million and $142 million, respectively, compared to $40 million and $133 million for the three and nine months ended September 30, 2024, respectively. The increase for both periods was primarily attributable to fixed asset additions during the 2025 Turnaround and the turnaround at the Wynnewood Refinery during 2024 (the "2024 Turnaround"), partially offset by certain assets being retired or fully depreciated prior to the current period.
Selling, General, and Administrative Expenses - For the three and nine months ended September 30, 2025, selling, general and administrative expenses was $24 million and $65 million, respectively, compared to $23 million and $57 million for the three and nine months ended September 30, 2024, respectively. The increase for the nine months ended September 30, 2025 was primarily due to increased share-based compensation as a result of an increase in the market price of CVR Energy's common shares in the current year period and a decrease in the market price of CVR Energy's common shares in the prior year period, partially offset by lower legal expenses and charitable contributions in the current year period.
Renewables Segment
The Renewables Segment utilizes certain inputs within its refining operations. These inputs include corn oil, soybean oil, and other vegetable oils (these are also known as "throughputs").
Renewables Throughput and Production Data
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
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| (in gallons per day) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Throughput Data | |||||||||||||||||||||||
| Corn Oil | - | 64,548 | 6,718 | 44,952 | |||||||||||||||||||
| Soybean Oil | 207,549 | 149,357 | 166,207 | 94,008 | |||||||||||||||||||
| Production Data | |||||||||||||||||||||||
| Renewable diesel | 190,464 | 193,649 | 161,178 | 124,759 | |||||||||||||||||||
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Renewable utilization (1)
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82.4 | % | 84.9 | % | 68.6 | % | 55.1 | % | |||||||||||||||
| Renewable diesel yield (as % of corn and soybean oil throughput) | 91.8 | % | 90.5 | % | 93.2 | % | 89.8 | % | |||||||||||||||
(1)Total corn and soybean oil throughput divided by total renewable throughput capacity of 252,000 gallons per day.
September 30, 2025 | 46
Renewables Segment Financial Highlights
Overview -The Renewables Segment's operating loss and net loss were both $51 million for the three months ended September 30, 2025, compared to operating income and net income of $3 million each for the three months ended September 30, 2024. The changes in operating loss and net loss compared to the prior period were primarily due to accelerated depreciation related to certain assets to be retired by the end of 2025 combined with lower HOBO spread and the loss of the BTC in the current period, partially offset by increased revenue resulting from higher RINs prices in the current period. For the nine months ended September 30, 2025, the Renewables Segment's operating loss and net loss were $63 million and $62 million, respectively, compared to operating loss and net loss of $18 million each for the nine months ended September 30, 2024. The increases in both operating loss and net loss compared to the prior period were primarily due to accelerated depreciation related certain assets to be retired by the end of 2025, the lower HOBO spread, and the loss of the BTC in the current period, partially offset by increased revenue from higher RINs prices and increased production and sales volumes in the current period as a result of reduced rates from a delayed restart to the RDU during both the 2024 Turnaround and the 2024 catalyst change, as well as the Wynnewood Fire.
| Renewables Net Sales |
Renewables Operating (Loss) Income
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Renewables Net (Loss) Income
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Renewables EBITDA (1)
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(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measure shown above.
September 30, 2025 | 47
Net Sales- For the three and nine months ended September 30, 2025, net sales for the Renewables Segment was $99 million and $240 million, respectively, compared to $99 million and $196 million for the three and nine months ended September 30, 2024, respectively. Net sales for the three months ended September 30, 2025 were impacted by increased D4 RIN and CARB ULSD prices, offset by the loss of the BTC and a decrease in the LCFS diesel compliance standard beginning July 1, 2025 resulting in lower generation of LCFS credits in the current period. The increase in net sales for the nine months ended September 30, 2025 was primarily due to increased production and sales volumes coupled with increased D4 RIN prices, partially offset by the loss of the BTC and a decrease in average CARB ULSD prices.
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Q3 Renewables Margin (1)
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YTD Renewables Margin (1)
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(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measures shown above.
Renewables Margin - For the three and nine months ended September 30, 2025, renewables margin was less than $(1) million and $21 million, respectively, compared to $21 million and $31 million for the three and nine months ended September 30, 2024. The primary factors contributing to the decrease in renewables margin in the current periods were:
•A decrease in revenue resulting from the expiration of the BTC on December 31, 2024;
•A decrease in the HOBO during three and nine months ended September 30, 2025 spread of $0.57 and $0.40 per gallon, respectively;
•A decrease of inventory net realizable value resulting in write-downs of $9 million and $12 million for the three and nine months ended September 30, 2025, respectively;
•Decreased production and sales volumes during the three months ended September 30, 2025; and
•A decrease in the LCFS diesel compliance standard beginning July 1, 2025 which reduced generation of LCFS credits.
Factors partially offsetting the above decreases were:
•Increased production and sales volumes during the nine months ended September 30, 2025;
•An increase in D4 RINs prices; and
•An increase in renewable diesel yield due to improved catalyst performance in the current periods.
For the three and nine months ended September 30, 2025, renewables margin per vegetable oil throughput gallon was $(0.01) and $0.44, respectively, compared to $1.09 and $0.81 for the three and nine months ended September 30, 2024, respectively. The decreases for the three and nine months ended September 30, 2025 compared to the prior year periods were primarily attributable to the decreased HOBO spread and decrease in revenue resulting from the expiration of the BTC on December 31, 2024 and the lower LCFS diesel compliance standard beginning July 1, 2025, partially offset by the increase in D4 RINs prices and sales volumes and an increase in the renewable diesel yield due to improved catalyst performance in the current period. The decrease for the nine months ended September 30, 2025 was further impacted by increased throughput in the current period as a result of the Wynnewood Fire in the prior year period.
September 30, 2025 | 48
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Q3 Renewables Direct Operating Expenses (1)
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YTD Renewables Direct Operating Expenses (1)
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(1)Exclusive of depreciation and amortization expense.
Direct Operating Expenses (Exclusive of Depreciation and Amortization) - For the three and nine months ended September 30, 2025, direct operating expenses (exclusive of depreciation and amortization) were $9 million and $23 million, respectively, compared to $9 million and $24 million for the three and nine months ended September 30, 2024, respectively. On a vegetable oil throughput gallon basis, direct operating expenses decreased to $0.45 and $0.49 per gallon from $0.48 and $0.62 per gallon. The decrease for the nine months ended September 30, 2025 was primarily a function of increased throughput in the current period as a result of the Wynnewood Fire in the prior year period, combined with lower direct operating expenses. Direct operating expenses (exclusive of depreciation and amortization) for the three months ended September 30, 2025 was primarily impacted by lower expenses for insurance, repairs and maintenance, production chemicals and catalysts, offset by higher expenses for natural gas and electricity utilities and increased personnel costs. The decrease for the nine months ended September 30, 2025 was attributable to lower expenses for repairs and maintenance and insurance, partially offset by higher expenses for production chemicals and catalysts, natural gas and electricity utilities, and environmental and personnel costs in the current period.
Nitrogen Fertilizer Segment
Utilization and Production Volumes - The following tables summarize the consolidated ammonia utilization from the Coffeyville Fertilizer Facility and CVR Partners' facility in East Dubuque, Illinois ("the East Dubuque Fertilizer Facility"). Utilization is an important measure used by management to assess operational output at each of the Nitrogen Fertilizer Segment's facilities. Utilization is calculated as actual tons of ammonia produced divided by capacity.
Utilization is presented solely on ammonia production, rather than on each nitrogen product, as it provides a comparative baseline against industry peers and eliminates the disparity of facility configurations for upgrade of ammonia into other nitrogen products. With production primarily focused on ammonia upgrade capabilities, we believe this measure provides a meaningful view of how we operate.
Gross tons of ammonia represent the total ammonia produced, including ammonia produced that was upgraded into other fertilizer products. Net tons available for sale represents the ammonia available for sale that was not upgraded into other
September 30, 2025 | 49
fertilizer products. The table below presents all of these Nitrogen Fertilizer Segment metrics for the three and nine months ended September 30, 2025 and 2024:
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Three Months Ended September 30, |
Nine Months Ended September 30, |
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| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| Ammonia utilization rate | 95 | % | 97 | % | 96 | % | 96 | % | |||||||||||||||
| Production volumes (thousands of tons) | |||||||||||||||||||||||
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Ammonia (gross produced)
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208 | 212 | 621 | 626 | |||||||||||||||||||
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Ammonia (net available for sale)
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59 | 61 | 181 | 191 | |||||||||||||||||||
| UAN | 337 | 321 | 1,005 | 964 | |||||||||||||||||||
On a consolidated basis for the three months ended September 30, 2025, the Nitrogen Fertilizer Segment's utilization increased to 95% compared to 97% for the three months ended September 30, 2024 due primarily to planned downtime associated with control systems upgrades at the East Dubuque Fertilizer Facility and other minor unplanned outages at the Facilities during the third quarter of 2025 (the "Q3 2025 Outages"). For the nine months ended September 30, 2025, utilization was 96%, consistent with utilization for the nine months ended September 30, 2024. Utilization for the 2025 period was impacted primarily by the Q3 2025 Outages and outages related to the control systems upgrades at the East Dubuque Fertilizer Facility and other minor unplanned outages at the fertilizer facilities during the second quarter of 2025 (together with the Q3 2025 Outages, the "2025 Outages"), while the 2024 period was impacted by the 14-day planned outage at the Coffeyville Fertilizer Facility during the first quarter of 2024 and other minor unplanned outages at the Facilities (the "2024 Outages").
Sales and Pricing per Ton - Two of the Nitrogen Fertilizer Segment's key operating metrics are total sales volumes for ammonia and UAN, along with the product pricing per ton realized at the gate. Product pricing at the gate represents net sales less freight revenue divided by product sales volume in tons and is shown in order to provide a pricing measure comparable across the fertilizer industry.
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| Consolidated sales volumes (thousands of tons) | |||||||||||||||||||||||
| Ammonia | 48 | 62 | 165 | 175 | |||||||||||||||||||
| UAN | 328 | 336 | 1,009 | 950 | |||||||||||||||||||
| Consolidated product pricing at gate (dollars per ton) | |||||||||||||||||||||||
| Ammonia | $ | 531 | $ | 399 | $ | 561 | $ | 481 | |||||||||||||||
| UAN | 348 | 229 | 307 | 254 | |||||||||||||||||||
Feedstock - Our Coffeyville Fertilizer Facility utilizes a pet coke gasification process to produce nitrogen fertilizer. Our East Dubuque Fertilizer Facility uses natural gas in its production of ammonia. The table below presents these feedstocks for both fertilizer facilities within the Nitrogen Fertilizer Segment for the three and nine months ended September 30, 2025 and 2024:
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
|
Petroleum coke used in production (thousands of tons)
|
134 | 133 | 394 | 395 | |||||||||||||||||||
|
Petroleum coke used in production (dollars per ton)
|
$ | 44.58 | $ | 44.69 | $ | 47.86 | $ | 60.93 | |||||||||||||||
|
Natural gas used in production (thousands of MMBtus) (1)
|
2,114 | 2,082 | 6,171 | 6,443 | |||||||||||||||||||
|
Natural gas used in production (dollars per MMBtu) (1)
|
$ | 3.18 | $ | 2.19 | $ | 3.72 | $ | 2.40 | |||||||||||||||
(1)The feedstock natural gas shown above does not include natural gas used for fuel. The cost of fuel natural gas is included in Direct operating expenses (exclusive of depreciation and amortization).
September 30, 2025 | 50
Nitrogen Fertilizer Segment Financial Highlights (Three and Nine Months Ended September 30, 2025 versus September 30, 2024)
Overview -For the three months ended September 30, 2025, the Nitrogen Fertilizer Segment's operating income and net income were $51 million and $43 million, respectively, compared to operating income and net income of $11 million and $4 million, respectively, for the three months ended September 30, 2024. For the nine months ended September 30, 2025, the Nitrogen Fertilizer Segment's operating income and net income were $132 million and $109 million, respectively, compared to operating income and net income of $65 million and $43 million, respectively, for the nine months ended September 30, 2024. These increases were primarily due to higher revenues which were driven by increases in UAN and ammonia sales prices during the three and nine months ended September 30, 2025, as well as UAN sales volumes during the nine months ended September 30, 2025, partially offset by higher natural gas prices and lower ammonia sales volumes during the three and nine months ended September 30, 2025.
| Nitrogen Fertilizer Net Sales |
Nitrogen Fertilizer Operating Income
|
|||||||
|
Nitrogen Fertilizer Net Income
|
Nitrogen Fertilizer EBITDA (1)
|
|||||||
(1)See "Non-GAAP Reconciliations" section below for reconciliations of the non-GAAP measures shown above.
Net Sales - For the three months ended September 30, 2025, the Nitrogen Fertilizer Segment's net sales was $164 million compared to $125 million for the three months ended September 30, 2024. The increase was primarily due to favorable UAN and ammonia sales prices contributing $45 million in higher revenue, partially offset by decreased ammonia and UAN sales volumes reducing revenues by $7 million.
September 30, 2025 | 51
The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales, excluding urea products, freight, and other revenue, for the three months ended September 30, 2025 compared to the three months ended September 30, 2024:
| (in millions) | Price Variance | Volume Variance | |||||||||
| UAN | $ | 39 | $ | (2) | |||||||
| Ammonia | 6 | (5) | |||||||||
For the three months ended September 30, 2025 compared to the three months ended September 30, 2024, UAN and ammonia sales volumes decreased due to tight inventory levels as a result of higher sales earlier in the year, primarily due to strong demand. In addition, UAN and ammonia sales prices were favorable in 2025 due to improved market conditions, primarily driven by tight inventory levels. These inventory constraints resulted from increased demand arising from higher planting acreage in 2025, as well as domestic and international production outages that reduced global supply of nitrogen fertilizers. Higher natural gas prices also raised input costs, contributing to an overall increase in market prices.
For the nine months ended September 30, 2025, the Nitrogen Fertilizer Segment's net sales was $475 million compared to $386 million for the nine months ended September 30, 2024. This increase was primarily due to favorable UAN sales volumes and prices contributing $68 million in higher revenues, combined with favorable ammonia sales prices contributing $13 million in higher revenues, partially offset by decreased ammonia sales volumes reducing revenues by $5 million.
The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales, excluding urea products, freight, and other revenue, for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024:
| (in millions) | Price Variance | Volume Variance | |||||||||
| UAN | $ | 53 | $ | 15 | |||||||
| Ammonia | 13 | (5) | |||||||||
The increase in ammonia and UAN sales pricing for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024 was due to the same conditions described for the three-month period. The increase in UAN sales volumes for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024 was primarily attributable to higher UAN production volumes in the current period as a result of the 2024 Outages in the prior period, partially offset by the 2025 Outages. The decrease in ammonia sales volumes is primarily due to an increase in the volume of ammonia upgraded to other nitrogen products in the current period leading to less ammonia volumes available for sale.
Cost of Materials and Other - For the three and nine months ended September 30, 2025, cost of materials and other was $25 million and $86 million, respectively, compared to $26 million and $78 million for the three and nine months ended September 30, 2024, respectively. The decrease for the three months ended September 30, 2025 was driven primarily by decreased volumes sold and lower distribution costs, partially offset by increased natural gas prices. The increase for the nine months ended September 30, 2025 was driven primarily by increased natural gas prices, higher volumes of other purchased feedstocks, and increased distribution costs in the current period, partially offset by lower pet coke prices.
Non-GAAP Measures
Our management uses certain non-GAAP performance measures, and reconciliations to those measures, to evaluate current and past performance and prospects for the future to supplement our financial information presented in accordance with accounting principles generally accepted in the United States ("GAAP"). These non-GAAP financial measures are important factors in assessing our operating results and profitability and include the performance and liquidity measures defined below.
The following are non-GAAP measures we present for the periods ended September 30, 2025 and 2024:
EBITDA- Consolidated net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense.
September 30, 2025 | 52
Petroleum EBITDA, Renewables EBITDA, and Nitrogen Fertilizer EBITDA- Segment net income (loss) before segment (i) interest expense, net, (ii) income tax expense (benefit), and (iii) depreciation and amortization.
Refining Margin- The difference between our Petroleum Segment net sales and cost of materials and other.
Refining Margin per Throughput Barrel- Refining Margin divided by the total throughput barrels during the period, which is calculated as total throughput barrels per day times the number of days in the period.
Direct Operating Expenses per Throughput Barrel- Direct operating expenses for our 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.
Renewables Margin- The difference between our Renewables Segment net sales and cost of materials and other.
Renewables Margin per Vegetable Oil Throughput Gallon- 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.
Direct Operating Expenses per Vegetable Oil Throughput Gallon - Direct operating expenses for our 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.
Adjusted EBITDA, Petroleum Adjusted EBITDA, Renewables Adjusted EBITDA, and Nitrogen Fertilizer Adjusted EBITDA - EBITDA, Petroleum EBITDA, Renewables EBITDA, and Nitrogen Fertilizer EBITDA adjusted for certain significant noncash 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.
We present these measures because we believe they may help investors, analysts, lenders and ratings agencies analyze our results of operations and liquidity in conjunction with our U.S. GAAP results, including but not limited to our operating performance as compared to other publicly traded companies in the refining and fertilizer industries, without regard to historical cost basis or financing methods and our ability to incur and service debt and fund capital expenditures. 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. See "Non-GAAP Reconciliations" included herein for reconciliation of these amounts. Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document.
Factors Affecting Comparability of Our Financial Results
Our results of operations for the periods presented may not be comparable with prior periods or to our results of operations in the future for the reasons discussed below.
Petroleum Segment
Major Scheduled Turnaround Activities- Total capitalized expenditures as part of planned turnarounds were $165 million and $3 million during the three months ended September 30, 2025 and 2024, respectively, and $189 million and $45 million during the nine months ended September 30, 2025 and 2024, respectively.
Renewable Fuel Standard- Based on the 2025 SRE Decision, WRC's obligations for the 2020 through 2024 compliance periods were reduced by more than 424 million RINs, resulting in an RVO adjustment and a gain of $488 million to reflect the SRE waivers. Refer to Part I, Item 1, Note 12 ("Commitments and Contingencies") of this Report for further details.
Renewables Segment
During the third quarter of 2025, the Company resolved to revert the RDU at the Wynnewood Refinery back to hydrocarbon processing service at the next scheduled catalyst change in December 2025, considering the unfavorable economics of the renewables business and to optimize feedstock and relieve certain logistical constraints within the refining business. While the Company expects to maintain the option to switch back to renewable diesel service if incentivized to do so,
September 30, 2025 | 53
the remaining useful lives of certain assets within the Renewables Segment were adjusted as a result of changes in their expected utilization beginning in September 2025, which resulted in additional depreciation expense of $31 million during both the three and nine months ended September 30, 2025.
Non-GAAP Reconciliations
Reconciliation of Net Income to EBITDA and Adjusted EBITDA
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Net income (loss) | $ | 401 | $ | (122) | $ | 206 | $ | 5 | |||||||||||||||
| Interest expense, net | 25 | 18 | 79 | 56 | |||||||||||||||||||
| Income tax expense (benefit) | 88 | (6) | (3) | (14) | |||||||||||||||||||
| Depreciation and amortization | 111 | 75 | 258 | 224 | |||||||||||||||||||
| EBITDA | 625 | (35) | 540 | 271 | |||||||||||||||||||
| Adjustments: | |||||||||||||||||||||||
|
Changes in RFS liability, (favorable) unfavorable
|
(471) | 59 | (271) | (32) | |||||||||||||||||||
|
Unrealized loss on derivatives, net
|
8 | 9 | 6 | 16 | |||||||||||||||||||
|
Inventory valuation impacts, unfavorable (favorable)
|
18 | 30 | 27 | (6) | |||||||||||||||||||
| Adjusted EBITDA | $ | 180 | $ | 63 | $ | 302 | $ | 249 | |||||||||||||||
Reconciliation of Petroleum Segment Net Income (Loss) to EBITDA and Adjusted EBITDA
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Petroleum net income (loss) | $ | 520 | $ | (110) | $ | 223 | $ | 35 | |||||||||||||||
| Interest (income) expense, net | - | (5) | 5 | (16) | |||||||||||||||||||
| Depreciation and amortization | 52 | 40 | 142 | 133 | |||||||||||||||||||
| Petroleum EBITDA | 572 | (75) | 370 | 152 | |||||||||||||||||||
| Adjustments: | |||||||||||||||||||||||
|
Changes in RFS liability, (favorable) unfavorable (1)
|
(471) | 59 | (271) | (32) | |||||||||||||||||||
|
Unrealized loss on derivatives, net
|
8 | 9 | 7 | 16 | |||||||||||||||||||
|
Inventory valuation impacts, unfavorable (favorable)(2)
|
11 | 31 | 21 | (8) | |||||||||||||||||||
| Petroleum Adjusted EBITDA | $ | 120 | $ | 24 | $ | 127 | $ | 128 | |||||||||||||||
(1)Changes in the RFS liability include adjustments to reflect the 2025 SRE Decision in the amount of $488 million for the three and nine months ended September 30, 2025, as well as the revaluation of the RVO. Refer to Part I, Item 1, Note 12 ("Commitments and Contingencies") of this Report for further discussion.
(2)The Petroleum Segment's basis for determining inventory value under GAAP is First-In, First-Out ("FIFO"). Changes in crude oil prices can cause fluctuations in the inventory valuation of crude oil, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when crude oil prices increase and an unfavorable inventory valuation impact when crude oil prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period.
September 30, 2025 | 54
Reconciliation of Petroleum Segment Gross Profit (Loss) to Refining Margin
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Net sales | $ | 1,739 | $ | 1,648 | $ | 4,777 | $ | 5,165 | |||||||||||||||
| Less: | |||||||||||||||||||||||
| Cost of materials and other | (1,031) | (1,604) | (4,039) | (4,645) | |||||||||||||||||||
| Direct operating expenses (exclusive of depreciation and amortization) | (113) | (100) | (306) | (320) | |||||||||||||||||||
| Depreciation and amortization | (52) | (40) | (142) | (133) | |||||||||||||||||||
| Gross profit (loss) | 543 | (96) | 290 | 67 | |||||||||||||||||||
| Add: | |||||||||||||||||||||||
| Direct operating expenses (exclusive of depreciation and amortization) | 113 | 100 | 306 | 320 | |||||||||||||||||||
| Depreciation and amortization | 52 | 40 | 142 | 133 | |||||||||||||||||||
| Refining margin | $ | 708 | $ | 44 | $ | 738 | $ | 520 | |||||||||||||||
| Total throughput barrels per day | 215,968 | 189,294 | 169,848 | 190,427 | |||||||||||||||||||
| Days in the period | 92 | 92 | 273 | 274 | |||||||||||||||||||
| Total throughput barrels | 19,869,004 | 17,415,033 | 46,368,569 | 52,176,994 | |||||||||||||||||||
| Refining margin per total throughput barrel | $ | 35.65 | $ | 2.53 | $ | 15.93 | $ | 9.96 | |||||||||||||||
| Direct operating expenses per total throughput barrel | 5.69 | 5.72 | 6.62 | 6.14 | |||||||||||||||||||
Reconciliation of Renewables Segment Net (Loss) Income to EBITDA and Adjusted EBITDA
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Renewables net (loss) income | $ | (51) | $ | 3 | $ | (62) | $ | (18) | |||||||||||||||
|
Interest income, net
|
- | - | (1) | - | |||||||||||||||||||
| Depreciation and amortization | 36 | 6 | 50 | 18 | |||||||||||||||||||
| Renewables EBITDA | (15) | 9 | (13) | - | |||||||||||||||||||
| Adjustments: | |||||||||||||||||||||||
|
Inventory valuation impacts, unfavorable (favorable) (1) (2)
|
8 | (1) | 5 | 1 | |||||||||||||||||||
| Renewables Adjusted EBITDA | $ | (7) | $ | 8 | $ | (8) | $ | 1 | |||||||||||||||
(1)The Renewables Segment's basis for determining inventory value under GAAP is FIFO. Changes in renewable diesel and renewable feedstock prices can cause fluctuations in the inventory valuation of renewable diesel, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when renewable diesel prices increase and an unfavorable inventory valuation impact when renewable diesel prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period.
(2)Includes an inventory valuation charge of $2 million and $9 million for the three months ended June 30, 2025 and September 30, 2025, respectively, as inventories were reflected at the lower of cost or net realizable value. No adjustment was necessary for any other period in 2025 or 2024.
September 30, 2025 | 55
Reconciliation of Renewables Segment Gross (Loss) Profit to Renewables Margin
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions, except throughput data) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Net sales | $ | 99 | $ | 99 | $ | 240 | $ | 196 | |||||||||||||||
| Less: | |||||||||||||||||||||||
| Cost of materials and other | (99) | (78) | (219) | (165) | |||||||||||||||||||
| Direct operating expenses (exclusive of depreciation and amortization) | (9) | (9) | (23) | (24) | |||||||||||||||||||
| Depreciation and amortization | (36) | (6) | (50) | (18) | |||||||||||||||||||
|
Gross (loss) profit
|
(45) | 6 | (52) | (11) | |||||||||||||||||||
| Add: | |||||||||||||||||||||||
| Direct operating expenses (exclusive of depreciation and amortization) | 9 | 9 | 23 | 24 | |||||||||||||||||||
| Depreciation and amortization | 36 | 6 | 50 | 18 | |||||||||||||||||||
| Renewables margin | $ | - | $ | 21 | $ | 21 | $ | 31 | |||||||||||||||
| Total vegetable oil throughput gallons per day | 207,549 | 213,905 | 172,925 | 138,960 | |||||||||||||||||||
| Days in the period | 92 | 92 | 273 | 274 | |||||||||||||||||||
| Total vegetable oil throughput gallons | 19,094,515 | 19,679,181 | 47,208,459 | 38,074,830 | |||||||||||||||||||
| Renewables margin per vegetable oil throughput gallon | $ | (0.01) | $ | 1.09 | $ | 0.44 | $ | 0.81 | |||||||||||||||
| Direct operating expenses per vegetable oil throughput gallon | 0.45 | 0.48 | 0.49 | 0.62 | |||||||||||||||||||
Reconciliation of Nitrogen Fertilizer Segment Net Income to EBITDA and Adjusted EBITDA
|
Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||||||||||
| (in millions) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Nitrogen Fertilizer net income | $ | 43 | $ | 4 | $ | 109 | $ | 43 | |||||||||||||||
| Interest expense, net | 8 | 7 | 23 | 22 | |||||||||||||||||||
| Depreciation and amortization | 20 | 25 | 59 | 64 | |||||||||||||||||||
| Nitrogen Fertilizer EBITDA and Adjusted EBITDA | $ | 71 | $ | 36 | $ | 191 | $ | 129 | |||||||||||||||
Liquidity and Capital Resources
Our principal source of liquidity has historically been cash from operations. As further discussed below, our uses of cash are for working capital, capital and turnaround expenditures, funding our debt service obligations, and paying dividends to our stockholders when approved by the Board of Directors.
Certain external factors, such as volatile commodity pricing, higher industry utilization, and market oversupply have had an unfavorable impact on our business, especially within our Petroleum segment. Despite these challenges, we believe our current liquidity position continues to be sufficient to support our operations and capital needs for at least the next 12 months.
The Company successfully completed a major turnaround at the Coffeyville Refinery in April 2025 and, during the second and third quarters of 2025, applied $70 million and $20 million, respectively, towards prepayments of the Term Loan. These decisions reflect the Company's continued focus on financial discipline and maintaining adequate capital to support operations throughout this environment of uncertainty. The Board will continue to evaluate the economic environment, the Company's liquidity needs, optimal uses of cash, payment of dividends (if any), and other relevant factors, and may elect to make additional changes to the Company's capital allocation in future periods.
September 30, 2025 | 56
Based on the 2025 SRE Decision, WRC's obligations for the 2020 through 2024 compliance periods were reduced by more than 424 million RINs, representing approximately $488 million.
Despite the favorable precedent from the 2025 SRE Decision, the Company continues to accrue WRC's 2025 RFS obligation at 100% of the required amount as no waiver has yet been granted for the 2025 compliance year. The Company currently estimates that WRC's 2025 obligation will represent approximately 120 million RINs as of the end of the current fiscal year absent a waiver. No assurance can be given regarding the outcome or timing of the EPA's decision, and the Company has not recognized any adjustment to its 2025 recorded RFS liability at this time.
The Company plans to satisfy WRC's remaining RIN obligations by year-end through a combination of available RINs held in inventory, along with open market purchases funded by operational cash flows, and other liquidity measures. Management will continue to monitor developments of the RFS program and will adjust its compliance strategy as needed for future obligations.
While we believe that our cash from operations and existing cash and cash equivalents, along with borrowings from available lines of credit, as necessary, will be sufficient to satisfy anticipated cash requirements associated with our existing operations for at least the next 12 months, our future expenditures for turnaround, capital expenditures and other cash requirements could be higher than we currently expect as a result of various factors including, but not limited to, rising material and labor costs, other inflationary pressures, interest rate fluctuations, and the costs associated with complying with the RFS and the outcome of litigation and other factors. Additionally, potential supply chain disruptions, geopolitical and economy instability, volatility in energy prices, the impacts of increasing electric vehicles and liquid natural gas and other improvements in fuel efficiencies and changes in regulatory policies could adversely affect our operations. Our ability to generate sufficient cash from our operating activities in the current commodity price environment, sell non-core assets, access capital markets, incur additional debt or take any other action to improve our liquidity is subject to the risks discussed above and elsewhere in our periodic reports and the other risks and uncertainties that exist in our industry, and depends on our future operational performance, which is subject to general economic, political, financial, competitive, and other factors, some of which may be beyond our control. Furthermore, shifts in demand and tightening credit market conditions could impact our financial stability.
Depending on the needs of our business, contractual limitations, and market conditions, we may, from time to time, seek to issue equity securities, incur additional debt, issue debt securities, or redeem, repurchase, refinance, or retire our outstanding debt through privately negotiated transactions, open market repurchases, redemptions, exchanges, tender offers or otherwise. There can be no assurance that we will seek to do any of the foregoing or that we will be able to do any of the foregoing on terms acceptable to us or at all. We closely monitor the amounts and timing of our sources and uses of funds and the availability of borrowings, if any, under the CVR Energy ABL. Our ability to incur additional indebtedness could be restricted by the terms of our existing senior notes, the CVR Energy ABL, or the Term Loan.
The Company and its subsidiaries were in compliance with applicable financial covenants under their respective debt instruments as of September 30, 2025, and through the date of filing of this Report, as applicable.
Cash Balances and Other Liquidity
As of September 30, 2025, we had total liquidity of approximately $1.0 billion, which consists of $670 million of consolidated cash and cash equivalents, $316 million available under the CVR Energy ABL, and $50 million available under the CVR Partners' Credit Agreement ("CVR Partners ABL"). As of December 31, 2024, we had total liquidity of approximately $1.3 billion, which consisted of $987 million of consolidated cash and cash equivalents, $238 million available under the CVR Energy ABL, and $39 million available under the CVR Partners ABL.
September 30, 2025 | 57
Long-term debt consisted of the following:
| (in millions) | September 30, 2025 | December 31, 2024 | |||||||||
| CVR Energy: | |||||||||||
|
8.50% Senior Notes, due January 2029
|
$ | 600 | $ | 600 | |||||||
|
5.75% Senior Notes, due February 2028
|
400 | 400 | |||||||||
| Unamortized debt issuance costs | (3) | (4) | |||||||||
| Total CVR Energy debt | 997 | 996 | |||||||||
|
Petroleum Segment:
|
|||||||||||
| Term Loan | 229 | 322 | |||||||||
| Unamortized debt discount and debt issuance costs | (5) | (8) | |||||||||
|
Total Petroleum Segment debt
|
224 | 314 | |||||||||
|
Nitrogen Fertilizer Segment:
|
|||||||||||
|
6.125% Senior Secured Notes, due June 2028
|
550 | 550 | |||||||||
| Unamortized debt issuance costs | (2) | (2) | |||||||||
|
Total Nitrogen Fertilizer Segment debt
|
548 | 548 | |||||||||
| Total long-term debt | 1,769 | 1,858 | |||||||||
| Current portion of long-term debt | 3 | 3 | |||||||||
| Total long-term debt, including current portion | $ | 1,772 | $ | 1,861 | |||||||
Refer to Part II, Item 8, Note 8 ("Long-Term Debt and Finance Lease Obligations") of our 2024 Form 10-K for further discussion of these debt instruments.
Capital Spending
We divide capital spending needs into two categories: maintenance and growth. Maintenance capital spending includes non-discretionary maintenance projects and projects required to comply with environmental, health, and safety regulations. Growth capital projects generally involve an expansion of existing capacity, reliability improvements, and/or a reduction in direct operating expenses. We undertake growth capital spending based on the expected return on incremental capital employed, which is typically funded by reserves taken in prior years.
Our total capital expenditures for the nine months ended September 30, 2025, along with our estimated expenditures for 2025, by segment, are as follows:
|
Nine Months Ended September 30, 2025 Actual |
2025 Estimate
|
|||||||||||||||||||||||||||||||
| Maintenance | Growth | Total | ||||||||||||||||||||||||||||||
|
(in millions)
|
Maintenance | Growth | Total | Low | High | Low | High | Low | High | |||||||||||||||||||||||
| Petroleum | $ | 70 | $ | 28 | $ | 98 | $ | 82 | $ | 87 | $ | 34 | $ | 38 | $ | 116 | $ | 125 | ||||||||||||||
| Renewables | 2 | 1 | 3 | 3 | 4 | 1 | 2 | 4 | 6 | |||||||||||||||||||||||
| Nitrogen Fertilizer | 18 | 12 | 30 | 39 | 42 | 19 | 23 | 58 | 65 | |||||||||||||||||||||||
| Other | - | 1 | 1 | 1 | 2 | 1 | 2 | 2 | 4 | |||||||||||||||||||||||
| Total | $ | 90 | $ | 42 | $ | 132 | $ | 125 | $ | 135 | $ | 55 | $ | 65 | $ | 180 | $ | 200 | ||||||||||||||
Our estimated capital expenditures are subject to further change due to changes in capital projects' cost, scope, and completion time. For example, we may experience labor or equipment cost changes necessary to comply with government regulations or to complete projects that sustain the operations of the refineries or facilities. The UAN GP Board determines CVR Partners' capital spending. We will continue to monitor market conditions and make adjustments, if needed, to our current capital spending or turnaround plans. We may also accelerate or defer some capital expenditures from time to time. For example, as described further above, volatile commodity pricing and higher industry utilization and oversupply have had an unfavorable impact on our business and have negatively impacted our cash from operating activities and liquidity. As a result,
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in October 2024, the Board elected to suspend payment of the cash dividend, defer new growth capital spending, and reduce certain expected capital expenditures, as further discussed under "Liquidity and Capital Resources" above.
There are currently no additional turnarounds planned in the Petroleum Segment for the remainder of 2025 or 2026. The Petroleum Segment's total capitalized expenditures were $165 million and $3 million during the three months ended September 30, 2025 and 2024, respectively, and $189 million and $45 million during the nine months ended September 30, 2025 and 2024, respectively.
The Coffeyville Fertilizer Facility's planned turnaround commenced in early October 2025, with an estimated cost of approximately $17 million, and is expected to last 33 days. The next planned turnaround for the Nitrogen Fertilizer Segment is currently scheduled to commence in the third quarter of 2026 at the East Dubuque Fertilizer Facility. Turnaround costs in the Nitrogen Fertilizer Segment are not capitalized, but instead are expensed as incurred within Direct operating expenses (exclusive of depreciation and amortization), and are expected to be funded through cash reserves taken during the three years preceding the turnaround.
Cash Requirements
There have been no material changes to the cash requirements disclosed in our Annual Report on Form 10-K for the year ended December 31, 2024, outside the ordinary course of business, except as follows:
Debt obligations - On June 30, 2025, certain of the Company's subsidiaries (the "Term Loan Borrowers") prepaid $70 million in principal of the Term Loan, in addition to required principal and interest payments as set forth in the Term Loan. Further, on July 25, 2025, the Term Loan Borrowers prepaid an additional $20 million in principal of the Term Loan, plus any accrued and unpaid interest to the redemption date. Refer to Part I, Item 1, Note 7 ("Long-Term Debt and Finance Lease Obligations") of this Report for further discussion.
Dividends to CVR Energy Stockholders
Dividends, if any, including the payment, amount and timing thereof, are determined at the discretion of the Board. IEP, through its ownership of the Company's common stock, is entitled to receive dividends that are declared and paid by the Company based on the number of shares held at each record date. The following table presents quarterly dividends paid to the Company's stockholders, including IEP, during 2024 (amounts presented in the table below may not add to totals presented due to rounding):
|
Quarterly Dividends Paid (in millions)
|
||||||||||||||||||||||||||||||||
| Related Period | Date Paid |
Quarterly Dividends Per Share |
Public Stockholders | IEP | Total | |||||||||||||||||||||||||||
|
2023 - 4th Quarter
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March 11, 2024 | $ | 0.50 | $ | 17 | $ | 33 | $ | 50 | |||||||||||||||||||||||
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2024 - 1st Quarter
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May 20, 2024 | 0.50 | 17 | 33 | 50 | |||||||||||||||||||||||||||
|
2024 - 2nd Quarter
|
August 19, 2024 | 0.50 | 17 | 33 | 50 | |||||||||||||||||||||||||||
|
Total 2024 quarterly dividends
|
$ | 1.50 | $ | 51 | $ | 100 | $ | 151 | ||||||||||||||||||||||||
There were no quarterly dividends declared or paid during the fourth quarter of 2024, and first, second, and third quarter of 2025 related to the third and fourth quarter of 2024 and first and second quarter of 2025, respectively. The Board did not declare a dividend for the third quarter of 2025.
Distributions to CVR Partners' Unitholders
Distributions, if any, including the payment, amount and timing thereof, and UAN GP Board's distribution policy, including the definition of available cash, are subject to change at the discretion of the UAN GP Board. The following tables present quarterly distributions paid by CVR Partners to CVR Partners' unitholders, including amounts received by the
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Company and IEP, during 2025and 2024 (amounts presented in the tables below may not add to totals presented due to rounding):
|
Quarterly Distributions Per Common Unit |
Quarterly Distributions Paid (in millions)
|
|||||||||||||||||||||||||||||||||||||
| Related Period | Date Paid |
Public Unitholders |
IEP | CVR Energy | Total | |||||||||||||||||||||||||||||||||
| 2024 - 4th Quarter | March 10, 2025 | $ | 1.75 | $ | 11 | $ | - | $ | 7 | $ | 18 | |||||||||||||||||||||||||||
| 2025 - 1st Quarter | May 19, 2025 | 2.26 | 14 | 1 | 9 | 24 | ||||||||||||||||||||||||||||||||
|
2025 - 2nd Quarter
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August 18, 2025 | 3.89 | 25 | 1 | 15 | 41 | ||||||||||||||||||||||||||||||||
|
Total 2025quarterly distributions
|
$ | 7.90 | $ | 51 | $ | 2 | $ | 31 | $ | 83 | ||||||||||||||||||||||||||||
|
2023 - 4th Quarter
|
March 11, 2024 | $ | 1.68 | $ | 11 | $ | - | $ | 7 | $ | 18 | |||||||||||||||||||||||||||
|
2024 - 1st Quarter
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May 20, 2024 | 1.92 | 13 | - | 7 | 20 | ||||||||||||||||||||||||||||||||
|
2024 - 2nd Quarter
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August 19, 2024 | 1.90 | 13 | - | 7 | 20 | ||||||||||||||||||||||||||||||||
|
2024 - 3rd Quarter
|
November 18, 2024 | 1.19 | 7 | - | 5 | 13 | ||||||||||||||||||||||||||||||||
|
Total 2024 quarterly distributions
|
$ | 6.69 | $ | 44 | $ | - | $ | 26 | $ | 71 | ||||||||||||||||||||||||||||
For the third quarter of 2025, upon approval by the UAN GP Board on October 29, 2025, CVR Partners declared a distribution of $4.02 per common unit, or approximately $42 million, which is payable November 17, 2025 to unitholders of record as of November 10, 2025. Of this amount, CVR Energy and IEP will receive approximately $16 million and $1 million, respectively, with the remaining amount payable to public unitholders.
Cash Flows
The following table sets forth our consolidated cash flows for the periods indicated below:
| Nine Months Ended September 30, | |||||||||||||||||
| (in millions) | 2025 | 2024 | Change | ||||||||||||||
| Net cash provided by (used in): | |||||||||||||||||
|
Operating activities
|
$ | 144 | $ | 306 | $ | (162) | |||||||||||
|
Investing activities
|
(309) | (164) | (145) | ||||||||||||||
|
Financing activities
|
(152) | (794) | 642 | ||||||||||||||
| Net (decrease) increase in cash, cash equivalents, reserved funds, and restricted cash | $ | (317) | $ | (652) | $ | 335 | |||||||||||
Operating Activities
The change in net cash provided by operating activities for the nine months ended September 30, 2025, compared to the nine months ended September 30, 2024, was primarily attributable to a decrease in working capital resulting from unfavorable changes in accounts payable, inventory, and other current liabilities totaling approximately $296 million, mainly related to the 2025 Turnaround activities and RIN purchases. These impacts were partially offset by higher net income in 2025 of approximately $116 million after considering non-cash adjustments.
Investing Activities
The change in net cash used in investing activities for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024 was primarily due to an increase in turnaround expenditures of $150 million for the 2025 Turnaround compared to the 2024 Turnaround, partially offset by proceeds from the sale of assets and proceeds from insurance claims related to the Wynnewood Fire.
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Financing Activities
The change in net cash used for financing activities for the nine months ended September 30, 2025 compared to the net cash used in financing activities for the nine months ended September 30, 2024 was primarily due to the $600 million redemption of the 5.25% Senior Notes due 2025 in 2024 and no dividends paid to CVR Energy stockholders during 2025 compared to $151 million in dividends paid during 2024. This was partially offset by principal payments on the Term Loan of $92 million during 2025 and an increase in distributions paid to CVR Partners' noncontrolling interest holders of $16 million during 2025 compared to 2024.
Critical Accounting Estimates
Our critical accounting estimates are disclosed in the "Critical Accounting Estimates" section of our 2024 Form 10-K. No modifications have been made during the three and nine months ended September 30, 2025 to these estimates.
CVR Energy Inc. published this content on October 30, 2025, and is solely responsible for the information contained herein. Distributed via Edgar on October 30, 2025 at 20:46 UTC. If you believe the information included in the content is inaccurate or outdated and requires editing or removal, please contact us at [email protected]