[10-Q] CVR ENERGY INC Quarterly Earnings Report

Rhea-AI Filing Summary

CVR Energy (CVI) reported a sharp turnaround in Q3 2025, with net income of $401 million versus a $122 million loss a year ago. Operating income rose to $512 million on net sales of $1,944 million, driven largely by the EPA’s August decision affirming and granting small refinery exemptions that reduced Renewable Fuel Standard obligations.

The company recorded a $417 million RFS compliance benefit in the quarter and noted its RFS position at $93 million as of September 30, 2025, down from $323 million at year-end. Petroleum delivered operating income of $518 million, while Renewables posted a $51 million operating loss. Nitrogen Fertilizer contributed $51 million.

CVR will revert the Wynnewood renewable diesel unit to hydrocarbon service in December 2025, booking $31 million of accelerated depreciation in Q3 and a $3 million project write-off. Cash was $670 million (down from $987 million at December 31, 2024). The company prepaid $90 million of its petroleum term loan during Q2–Q3, with total long-term debt and finance leases at $1,841 million including current portion.

Insights

Refining & Chemicals Analyst

Q3 upside came chiefly from EPA SRE relief; core refining also strong.

CVR Energy posted a profit inflection, with operating income at $512M and net income at $401M. A key swing factor was the EPA’s August small refinery exemption decision, which reduced obligations by approximately $488M (over 424 million RINs) and produced a quarterly RFS compliance benefit of $417M. Petroleum segment operating income reached $518M, indicating favorable refining economics alongside the regulatory impact.

Renewables showed strain, with a $51M operating loss and $31M of accelerated depreciation tied to the December 2025 plan to revert the Wynnewood RDU to hydrocarbon service. Cash stood at $670M, and the company prepaid $90M on its term loan in Q2–Q3; total long‑term debt including current portion was $1,841M.

Actual outcomes hinge on future EPA actions (including the December 1, 2025 compliance date for 2024) and execution of the Wynnewood transition in December 2025. Segment earnings composition suggests results may vary with crack spreads and RFS dynamics.

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)
☑			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
			For the quarterly period ended			September 30, 2025
OR
☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from               to

Commission file number: 001-33492

CVR ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware

61-1512186

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer Identification No.)

2277 Plaza Drive, Suite 500, Sugar Land, Texas 77479

(Address of principal executive offices) (Zip Code)

(281) 207-3200

(Registrant’s telephone number, including area code)

_____________________________________________________________

Securities registered pursuant to Section 12(b) of the Act:

Title of each class			Trading Symbol(s)			Name of each exchange on which registered
Common Stock, $0.01 par value per share			CVI			The New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑     No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑     No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined by Rule 12b-2 of the Exchange Act). Yes ☐     No ☑

There were 100,530,599 shares of the registrant’s common stock outstanding at October 24, 2025.

Table of Contents

TABLE OF CONTENTS

CVR Energy, Inc. - Quarterly Report on Form 10-Q

September 30, 2025

PART I. Financial Information

PART II. Other Information

Item 1.

Financial Statements

6

Item 1.

Legal Proceedings

62

Condensed Consolidated Balance Sheets - September 30, 2025 and December 31, 2024 (unaudited)

6

Item 1A.

Risk Factors

62

Condensed Consolidated Statements of Operations - Three and Nine Months Ended September 30, 2025 and 2024 (unaudited)

7

Item 5.

Other Information

62

Condensed Consolidated Statements of Changes in Equity - Three and Nine Months Ended September 30, 2025 and 2024 (unaudited)

8

Item 6.

Exhibits

62

Condensed Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2025 and 2024 (unaudited)

9

Signatures

64

Notes to the Condensed Consolidated Financial Statements (unaudited)

10

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

27

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

61

Item 4.

Controls and Procedures

61

This Quarterly Report on Form 10-Q (including documents incorporated by reference herein) contains statements with respect to our expectations or beliefs as to future events. These types of statements are “forward-looking” and subject to uncertainties. See “Important Information Regarding Forward-Looking Statements” section of this filing.

September 30, 2025 | 2

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Important Information Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q (this “Report”) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), including, but not limited to, those under Part I, Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Report. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. All statements other than statements of historical fact, including without limitation, statements regarding future operations, financial position, estimated revenues and losses, growth, capital projects, stock or unit repurchases, impacts of legal proceedings, legislation, policies or regulations, timing of determinations and other interactions with, and submissions to, regulatory authorities and agencies, projected costs, prospects, plans and objectives of management are forward looking statements. The words “could”, “believe”, “anticipate”, “intend”, “estimate”, “expect”, “may”, “continue”, “predict”, “potential”, “project”, and similar terms and phrases are intended to identify forward-looking statements.

Although we believe our assumptions concerning future events are reasonable, a number of risks, uncertainties, and other factors could cause actual results and trends to differ materially from those projected or forward looking. Forward looking statements, as well as certain risks, contingencies or uncertainties that may impact our forward-looking statements, include but are not limited to the following:

•volatile margins in the refining industry and exposure to the risks associated with volatile crude oil, refined product and feedstock prices;

•the availability of adequate cash and other sources of liquidity for the capital, operating and other needs of our businesses;

•the effects of the Russia-Ukraine war and the tensions and conflict in the Middle East and any escalation, expansion, or resolution thereof, including with respect to impacts to commodity prices and other markets;

•the effects of changes in market conditions; market volatility; crude oil and other commodity prices; demand for those commodities, storage and transportation capacities and costs, inflation, and the impact of such changes on our operating results and financial condition;

•the ability to forecast our future financial condition, results of operations, revenues and expenses accurately or at all;

•the effects of transactions involving derivative instruments;

•political uncertainty and impacts to the oil and gas industry and the United States and global economies generally as a result of actions taken by the current administration or others in response thereto, including the imposition of tariffs and reactions thereto and changes in climate or other energy laws, rules, regulations, or policies;

•interruption in pipelines supplying feedstocks or distributing the petroleum business’ products;

•competition in the petroleum, renewables, and nitrogen fertilizer businesses, including potential impacts of domestic and global supply and demand or domestic or international duties, tariffs, or similar costs;

•capital expenditures;

•changes in our or our segments’ credit profiles and impacts thereof on cash needs or otherwise;

•the cyclical and seasonal nature of the petroleum, renewables, and nitrogen fertilizer businesses;

•the supply, availability and price levels of raw materials and feedstocks and the effects of inflation thereupon;

•existing and future laws, regulations, rules, policies, or rulings, including changes, amendments, reinterpretations or amplification thereof and the actions of the current administration or future administrations relating thereto, and including but not limited to those relating to the environment and climate change; crude oil, refined products, other hydrocarbons or renewable feedstocks or products; renewable or alternative energy or fuel sources; electric vehicles; emissions and impacts thereof; safety and security; or the export, transportation, storage, sale or production of hazardous chemicals, materials or substances including potential liabilities or capital requirements arising from such laws, regulations, rules, policies, or rulings and the impacts thereof on macroeconomic factors, consumer activity or otherwise;

•our production levels, including the risk of a material decline thereof, as well as potential operating hazards, downtime, and damage to our or our counterparties’ facilities and other assets from accidents, fires, severe weather, tornadoes, floods, wildfires, or other natural disasters, accidents or other unscheduled shutdowns or interruptions affecting our facilities, machinery, people, or equipment, or those of our suppliers or customers;

•the impact of weather on commodity supply or pricing and on the nitrogen fertilizer business including our ability to produce, market or sell fertilizer products profitability or at all;

•rulings, judgments or settlements in litigation, tax or other legal or regulatory matters;

September 30, 2025 | 3

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•the dependence of the nitrogen fertilizer business on customers and distributors including to transport goods and equipment and providers of feedstocks;

•the reliance on, or the ability to procure economically or at all, petroleum coke (“pet coke”) that our nitrogen fertilizer business purchases from our subsidiaries and third-party suppliers or the natural gas, electricity, oxygen, nitrogen, sulfur processing and compressed dry air and other products purchased from third parties by the nitrogen fertilizer and petroleum businesses and the facility operating risks associated with these third parties;

•risks of terrorism, cybersecurity attacks, and the security of chemical manufacturing facilities and other matters beyond our control;

•our lack of diversification of assets or operating and supply areas;

•the petroleum business’ and nitrogen fertilizer business’ dependence on significant customers and the creditworthiness and performance by counterparties;

•the potential loss of the nitrogen fertilizer business’ transportation cost advantage over its competitors;

•the potential inability to successfully implement our business strategies at all or on time and within budget, including significant capital programs or projects, turnarounds or other initiatives, and other projects;

•our ability to continue to license the technology used for our operations;

•the impact of refined product demand and declining inventories on refined product prices and crack spreads;

•Organization of Petroleum Exporting Countries’ (“OPEC”) and its allies’ production levels and pricing;

•the impact of renewable fuel credits, known as renewable identification numbers (“RINs”), pricing, our blending and purchasing activities, our ability to purchase RINs on a timely and cost effective basis or at all, and governmental actions, including by the U.S. Environmental Protection Agency (the “EPA”) on our RIN obligation, open RINs positions, small refinery exemptions, and our cost to comply with our Renewable Fuel Standard (“RFS”) obligations;

•our accounting policies and treatment, including of our RFS obligations;

•operational upsets or changes in laws that could impact the amount and receipt of credits (if any) under Section 45Q of the Internal Revenue Code of 1986, as amended, or any similar law, rule, or regulation;

•our ability to meet certain carbon capture and sequestration milestones;

•our businesses’ ability to obtain, retain or renew environmental and other governmental permits, licenses or authorizations necessary for the operation of its business;

•impact of potential runoff of water containing nitrogen based fertilizer into waterways and regulatory or legal actions in response thereto;

•our ability to issue securities, obtain financing or sell assets on terms favorable to us or at all;

•bank failures or other events affecting financial institutions;

•existing and future regulations related to the end-use of our products or the application of fertilizers;

•refinery, renewables, and nitrogen fertilizer facilities’ operating hazards and interruptions, including unscheduled maintenance or downtime and the availability of adequate insurance coverage;

•risks related to services provided by or competition among our subsidiaries, including conflicts of interests and control of the general partner of CVR Partners, LP (“CVR Partners”), and control of CVR Energy, Inc. (“CVR Energy”) by its controlling shareholder;

•risks related to our capital structure, including our authorization to issue additional common or preferred stock that may dilute equity ownership of current holders and the share price of our common stock;

•risks related to potential strategic transactions involving CVR Energy including, but not limited to, those in which its controlling shareholder or others may participate or direct and potential strategic transactions involving CVR Partners in which CVR Energy or its controlling shareholder or others may participate, including in each case the process of exploring any such transaction and potentially completing any such transaction, including the costs thereof and the risk that any such transaction may not achieve any or all of any anticipated benefits or be completed at all;

•instability and volatility in the capital and credit markets;

•restrictions in our debt agreements and our ability to refinance our debt on acceptable terms or at all;

•asset impairments and impacts thereof;

•our controlling shareholder’s intentions regarding ownership of our common stock or the common units of CVR Partners, including any acquisitions, dispositions or transactions relating thereto;

•the impact of any pandemic or breakout of infectious disease, and of businesses’ and governments’ responses thereto on our operations, personnel, commercial activity, and supply and demand across our and our customers’ and suppliers’ business;

•the variable nature of CVR Partners’ distributions, including the ability of its general partner to modify or revoke its distribution policy, or to cease making cash distributions on its common units;

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•changes in tax and other laws, regulations and policies, including, without limitation, the One Big Beautiful Bill Act and actions of the past, current or future administrations that impact conventional fuel operations or favor renewable energy projects in the United States;

•changes in CVR Partners’ treatment as a partnership for U.S. federal income or state tax purposes;

•our ability to procure or recover under our insurance policies for damages or losses in full or at all;

•labor supply shortages, labor difficulties, labor disputes or strikes;

•timing and impacts of any decision to modify a unit to hydrocarbon processing following renewable conversion, or vice versa, including the resolution made in the third quarter of 2025 to revert the renewable diesel unit at the refinery located in Wynnewood, Oklahoma to hydrocarbon processing service; and

•the factors described in greater detail under “Risk Factors” in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2024 and our other filings with the U.S. Securities and Exchange Commission (“SEC”).

All forward-looking statements contained in this Report only speak as of the date of this Report. We undertake no obligation to publicly update or revise any forward-looking statements to reflect events or circumstances that occur after the date of this Report, or to reflect the occurrence of unanticipated events, except to the extent required by law.

Information About Us

Investors should note that we make available, free of charge on our website at www.CVREnergy.com, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. We also post announcements, updates, events, investor information and presentations on our website in addition to copies of all recent news releases. We may use the Investor Relations section of our website to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. Documents and information on our website are not incorporated by reference herein.

The SEC maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers, including us, that file electronically with the SEC.

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PART I. FINANCIAL INFORMATION

Item 1.  Financial Statements

CVR ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(in millions)			September 30, 2025						December 31, 2024
ASSETS
Current assets:
Cash and cash equivalents (including $156 and $91, respectively, of consolidated variable interest entity (“VIE”))			$	670					$	987
Accounts receivable, net (including $48 and $65, respectively, of VIE)			253						295
Inventories (including $82 and $76, respectively, of VIE)			509						502
Prepaid expenses (including $1 and $1, respectively, of VIE)			23						16
Other current assets (including $1 and $1, respectively, of VIE)			23						24
Total current assets			1,478						1,824
Property, plant, and equipment, net (including $705 and $736, respectively, of VIE)			2,106						2,176
Other long-term assets (including $43 and $50, respectively, of VIE)			408						263
Total assets			$	3,992					$	4,263
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable (including $39 and $37, respectively, of VIE)			$	437					$	538
Other current liabilities (including $68 and $75, respectively, of VIE)			318						560
Total current liabilities			755						1,098
Long-term liabilities:
Long-term debt and finance lease obligations, net of current portion (including $569 and $568, respectively, of VIE)			1,827						1,907
Deferred income taxes			274						277
Other long-term liabilities (including $42 and $46, respectively, of VIE)			95						93
Total long-term liabilities			2,196						2,277
Commitments and contingencies (See Note 12)
CVR Energy stockholders’ equity:
Preferred stock, $0.01 par value per share; 50,000,000 shares authorized; none issued			—						—
Common stock, $0.01 par value per share; 350,000,000 shares authorized; 100,629,209 and 100,629,209 shares issued as of September 30, 2025 and December 31, 2024, respectively			1						1
Additional paid-in-capital			1,508						1,508
Accumulated deficit			(667)						(804)
Treasury stock, 98,610 shares at cost			(2)						(2)
Total CVR stockholders’ equity			840						703
Noncontrolling interest			201						185
Total equity			1,041						888
Total liabilities and equity			$	3,992					$	4,263

The accompanying notes are an integral part of these condensed consolidated financial statements.

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CVR ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited)

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions, except per share data)			2025						2024						2025						2024
Net sales			$	1,944					$	1,833					$	5,352					$	5,663
Operating costs and expenses:
Cost of materials and other			1,096						1,666						4,195						4,796
Direct operating expenses (exclusive of depreciation and amortization)			179						165						503						502
Depreciation and amortization			109						73						251						218
Cost of sales			1,384						1,904						4,949						5,516
Selling, general and administrative expenses (exclusive of depreciation and amortization)			42						40						115						103
Depreciation and amortization			2						2						7						6
Loss on asset disposals and project write-offs			4						—						4						1
Operating income (loss)			512						(113)						277						37
Other (expense) income:
Interest expense, net			(25)						(18)						(79)						(56)
Other income, net			2						3						5						10
Income (loss) before income tax expense			489						(128)						203						(9)
Income tax expense (benefit)			88						(6)						(3)						(14)
Net income (loss)			401						(122)						206						5
Less: Net income attributable to noncontrolling interest			27						2						69						27
Net income (loss) attributable to CVR Energy stockholders			$	374					$	(124)					$	137					$	(22)
Basic and diluted earnings (loss) per share			$	3.72					$	(1.24)					$	1.37					$	(0.22)
Weighted-average common shares outstanding:
Basic and diluted			100.5						100.5						100.5						100.5

The accompanying notes are an integral part of these condensed consolidated financial statements.

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CVR ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

			Common Stockholders
(in millions, except share data)			Shares Issued						$0.01 Par Value Common Stock						Additional Paid-In Capital						Accumulated Deficit						Treasury Stock												Total CVR Stockholders’ Equity						Noncontrolling Interest						Total Equity
Balance at December 31, 2024			100,629,209						$	1					$	1,508					$	(804)					$	(2)											$	703					$	185					$	888
Net (loss) income			—						—						—						(123)						—												(123)						18						(105)
Distributions from CVR Partners to its public unitholders and IEP			—						—						—						—						—												—						(12)						(12)
Balance at March 31, 2025			100,629,209						1						1,508						(927)						(2)												580						191						771
Net (loss) income			—						—						—						(114)						—												(114)						24						(90)
Distributions from CVR Partners to its public unitholders and IEP			—						—						—						—						—												—						(15)						(15)
Balance at June 30, 2025			100,629,209						1						1,508						(1,041)						(2)												466						200						666
Net income			—						—						—						374						—												374						27						401
Distributions from CVR Partners to its public unitholders and IEP			—						—						—						—						—												—						(26)						(26)
Balance at September 30, 2025			100,629,209						$	1					$	1,508					$	(667)					$	(2)											$	840					$	201					$	1,041

			Common Stockholders
(in millions, except share data)			Shares Issued						$0.01 Par Value Common Stock						Additional Paid-In Capital						Accumulated Deficit						Treasury Stock												Total CVR Stockholders’ Equity						Noncontrolling Interest						Total Equity
Balance at December 31, 2023			100,629,209						$	1					$	1,508					$	(660)					$	(2)											$	847					$	191					$	1,038
Net income			—						—						—						82						—												82						8						90
Dividends to CVR Energy stockholders			—						—						—						(50)						—												(50)						—						(50)
Distributions from CVR Partners to its public unitholders			—						—						—						—						—												—						(11)						(11)
Balance at March 31, 2024			100,629,209						1						1,508						(628)						(2)												879						188						1,067
Net income			—						—						—						21						—												21						17						38
Dividends to CVR Energy stockholders			—						—						—						(50)						—												(50)						—						(50)
Distributions from CVR Partners to its public unitholders			—						—						—						—						—												—						(13)						(13)
Other			—						—						—						(1)						—												(1)						—						(1)
Balance at June 30, 2024			100,629,209						1						1,508						(658)						(2)												849						192						1,041
Net (loss) income			—						—						—						(124)						—												(124)						2						(122)
Dividends paid to CVR Energy stockholders			—						—						—						(50)						—												(50)						—						(50)
Distributions from CVR Partners to its public unitholders			—						—						—						—						—												—						(13)						(13)
Balance at September 30, 2024			100,629,209						$	1					$	1,508					$	(832)					$	(2)											$	675					$	181					$	856

The accompanying notes are an integral part of these condensed consolidated financial statements.

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CVR ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

			Nine Months Ended September 30,
(in millions)			2025						2024
Cash flows from operating activities:
Net income (loss)			$	206					$	5
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization			258						224
Loss on lower of cost or net realizable value adjustment			12						—
Deferred income taxes and unrecognized tax benefits			(3)						(17)
Share-based compensation			37						13
Unrealized loss on derivatives, net			6						16
Income from equity method investments			(3)						(10)
Return from equity method investment earnings			4						11
Other items			12						7
Changes in working capital:
Accounts receivables			42						5
Inventories			(27)						107
Income tax receivable			3						(32)
Prepaid expenses and other current assets			(14)						26
Accounts payable			(137)						(71)
Accrued income taxes			—						(25)
Deferred revenue			(20)						19
Other current liabilities			(232)						28
Net cash provided by operating activities			144						306
Cash flows from investing activities:
Capital expenditures			(130)						(124)
Turnaround expenditures			(196)						(46)
Proceeds from sale of assets			8						1
Insurance proceeds related to asset damages			3						—
Return of equity method investment			6						5
Net cash used in investing activities			(309)						(164)
Cash flows from financing activities:
Principal payments of long-term debt			(92)						—
Principal payments on senior secured notes			—						(600)
Dividends to CVR Energy stockholders			—						(151)
Distributions to CVR Partners noncontrolling interest holders			(53)						(37)
Other financing activities			(7)						(6)
Net cash used in financing activities			(152)						(794)
Net decrease in cash, cash equivalents			(317)						(652)
Cash, cash equivalents, reserved funds, and restricted cash, beginning of period (1)			987						1,186
Cash and cash equivalents, end of period			$	670					$	534

(1)As of December 31, 2023, consisted of $581 million of cash and cash equivalents, $598 million of reserved funds, and $7 million of restricted cash. The reserved funds and restricted cash were released in the first quarter of 2024.

The accompanying notes are an integral part of these condensed consolidated financial statements.

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

(1) Organization and Nature of Business

Organization

CVR Energy, Inc. (“CVR Energy”, “CVR”, “we”, “us”, “our”, or the “Company”) 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 refines and markets high value transportation fuels which consist of gasoline, diesel, jet fuel, and distillates, as well as activities related to crude oil gathering and logistics that support refinery operations. The Renewables Segment refines renewable feedstocks, such as soybean oil, corn oil, and other renewable feedstocks, into renewable diesel and markets renewables products. CVR Partners produces and markets nitrogen fertilizer products primarily in the form of ammonia and urea ammonium nitrate (“UAN”) for the farming industry. CVR’s common stock is listed on the New York Stock Exchange (“NYSE”) under the symbol “CVI”. As of September 30, 2025, Icahn Enterprises L.P. and its affiliates, including Mr. Carl C. Icahn (“IEP”), owned approximately 70% of the Company’s outstanding common stock.

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 Note 4 (“Long-Term Assets”) for further discussion.

CVR Partners, LP

As of September 30, 2025, public common unitholders held approximately 60% of CVR Partners’ outstanding common units; CVR Energy, through its subsidiaries, held approximately 37% of CVR Partners’ outstanding common units and 100% of CVR Partners’ general partner interests, while IEP held approximately 3% of CVR Partners’ outstanding common units. The noncontrolling interest reflected on the Condensed Consolidated Balance Sheets of CVR is only impacted by the results of and distributions from CVR Partners.

Environmental Protection Agency (“EPA”) Small Refinery Exemption (“SRE”) Decision

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 decision document the EPA issued to the Company’s subsidiary, Wynnewood Refining Company, LLC (“WRC”), affirmed the validity of its previous grant of WRC’s petitions for small refinery hardship relief under the Renewable Fuel Standard (“RFS”) for 2017 and 2018 compliance periods and granted full or partial waivers for the 2019 through 2024 compliance periods. Refer to Note 12 (“Commitments and Contingencies”) for further details.

Subsequent Events

The Company evaluated subsequent events, if any, that would require an adjustment to the Company’s condensed consolidated financial statements or require disclosure in the notes thereto through the date of issuance. Where applicable, the notes to these condensed consolidated financial statements have been updated to reflect all significant subsequent events which have occurred.

(2) Basis of Presentation

The accompanying condensed consolidated financial statements, prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”), include the accounts of the Company and its majority-owned direct and indirect subsidiaries. All intercompany accounts and transactions have been eliminated. Certain notes and other information have been condensed or omitted from these condensed consolidated financial statements. Therefore, the accompanying condensed consolidated financial statements should be read in conjunction with the December 31, 2024 audited consolidated financial

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

statements and notes thereto included in CVR Energy’s Annual Report on Form 10-K for the year ended December 31, 2024 (the “2024 Form 10-K”).

Our condensed consolidated financial statements include the consolidated results of CVR Partners, which is defined as a variable interest entity (“VIE”). As the 100% owner of the general partner of CVR Partners, the Company has the sole ability to direct the activities that most significantly impact the economic performance of CVR Partners and is considered the primary beneficiary.

In the opinion of the Company’s management, the accompanying condensed consolidated financial statements reflect all adjustments that are necessary for fair presentation of the financial position and results of operations of the Company for the periods presented. Such adjustments are of a normal recurring nature, unless otherwise disclosed.

The condensed consolidated financial statements are prepared in conformity with GAAP, which requires management to make certain estimates and assumptions that affect the reported amounts and disclosure of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2025 or any other interim or annual period.

Reclassifications

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. Results of the Renewables Segment were not previously included within our reportable segments, rather included within “Other.” Prior period segment information has been retrospectively adjusted to reflect the current segment presentation. Refer to Note 13 (“Business Segments”) for segment disclosures.

In addition, certain other immaterial reclassifications have been made within the consolidated financial statements for prior periods to conform with current presentation.

Income Tax

On July 4, 2025, the One Big Beautiful Bill Act (“OBBB”) was enacted, introducing significant amendments to federal tax law and permanently extending several provisions of the 2017 Tax Cuts and Jobs Act (“TCJA”). The Company expects to benefit from the permanent extension of certain TCJA provisions, including 100% bonus depreciation and modifications to the business interest limitation. The Company does not anticipate any material impacts to its income tax balances as a result of the OBBB, but will continue to monitor legislative developments and evaluate any potential future impacts of the new law on its consolidated financial statements.

Our effective income tax rates for the three and nine months ended September 30, 2025 were 17.9% and (1.6)%, compared to 4.6% and 155.0% for the three and nine months ended September 30, 2024. These changes were 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.

Recent Accounting Pronouncements - Accounting Standards Issued But Not Yet Implemented

In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740) - Improvements to Income Tax Disclosures, which requires enhanced income tax disclosures that reflect how operations and related tax risks, as well as how tax planning and operational opportunities, affect the tax rate and prospects for future cash flows. This standard is effective for the Company’s annual reporting beginning January 1, 2025 with early adoption permitted. The adoption of this standard update will not have a material impact on the Company’s consolidated financial statements but additional disclosures will be included for our Annual Report on Form 10-K for the year ending December 31, 2025.

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

In November 2024, the FASB issued ASU 2024-03, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures (Subtopic 220-40), which requires additional disclosures in the footnotes that disaggregate certain expenses presented on the face of the income statement. This standard is effective for the Company’s annual reporting period beginning January 1, 2027 and interim reporting periods beginning January 1, 2028. Retrospective application to comparative periods is optional, and early adoption is permitted. The Company continues to evaluate and assess potential impacts of adopting this new accounting guidance.

In September 2025, the FASB issued ASU 2025-06, Intangibles (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software, which amends certain aspects of the accounting for and disclosure of software costs under ASC 350-40, including the elimination of accounting consideration of software project development stages and enhancement of the guidance around the ‘probable-to-complete’ threshold. This standard is effective for the Company’s annual and interim reporting periods beginning January 1, 2028. Retrospective application to comparative periods is optional, and early adoption is permitted. The Company is evaluating the effects of adopting this new accounting guidance.

(3) Inventories

Inventories consisted of the following:

(in millions)			September 30, 2025						December 31, 2024
Finished goods			$	217					$	221
Raw materials			140						146
In-process inventories			39						28
Parts, supplies and other			113						107
Total inventories			$	509					$	502

At September 30, 2025, the Renewables Segment had inventories with carrying amounts exceeding their net realizable value, which is estimated using indicative market pricing available at the time the estimate was made. As a result, we recognized a loss of $9 million and $12 million for the three and nine months ended September 30, 2025, respectively, in Cost of materials and other in the Company’s Condensed Consolidated Statements of Operations to reflect the net realizable value of such inventories. No adjustment was necessary for the three and nine months ended September 30, 2024.

(4) Long-Term Assets

Property, Plant, and Equipment

Property, plant, and equipment, net consisted of the following:

(in millions)			September 30, 2025						December 31, 2024
Machinery and equipment			$	4,458					$	4,403
Buildings and improvements			153						148
ROU finance leases			122						106
Land and improvements			75						74
Furniture and fixtures			29						32
Construction in progress			179						171
Other			16						16
			5,032						4,950
Less: Accumulated depreciation and amortization			(2,926)						(2,774)
Total property, plant, and equipment, net			$	2,106					$	2,176

For the three and nine months ended September 30, 2025, depreciation and amortization expense related to property, plant, and equipment was $89 million and $203 million, respectively, compared to $63 million and $177 million for the three and nine months ended September 30, 2024, respectively. For the three and nine months ended September 30, 2025, capitalized interest

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

was $2 million and $7 million, respectively, compared to $2 million and $5 million for the three and nine months ended September 30, 2024, respectively.

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, the following impacts were recorded in our Renewables Segment during the third quarter of 2025:

•The Company assessed the Petroleum and Renewables asset group for impairment in accordance with ASC 360-10 and concluded the carrying value of the asset group was recoverable. However, 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. As of September 30, 2025, approximately $93 million carrying value of the impacted property, plant and equipment will be fully depreciated through November 2025. Depreciation expense related to the Renewables Segment for the three and nine months ended September 30, 2025, was $36 million and $48 million, respectively, including $31 million of accelerated depreciation for the three months ended September 30, 2025, compared to $6 million and $17 million for the three and nine months ended September 30, 2024, respectively.

•The Company reviewed its ongoing capital projects and determined that certain Construction in progress assets relate to projects the Company no longer plans to complete or utilize in current or future operations. As a result, the Company recognized in Loss on asset disposals and project write-offs a charge of approximately $3 million to write-off these capitalized costs during the three months ended September 30, 2025. All other projects under construction were determined to remain realizable for current or future operations.

Other Long-Term Assets

As of September 30, 2025 and December 31, 2024, Other long-term assets included turnaround assets, net of accumulated amortization of $264 million and $124 million, respectively. For the three and nine months ended September 30, 2025, depreciation expense related to turnaround assets was $1 million and $2 million, respectively, compared to less than $1 million for both the three and nine months ended September 30, 2024.

(5) Leases

Balance Sheet Summary as of September 30, 2025 and December 31, 2024

The following table summarizes the right-of-use (“ROU”) asset and lease liability balances for the Company’s operating and finance leases at September 30, 2025 and December 31, 2024:

			September 30, 2025												December 31, 2024
(in millions)			Operating Leases						Finance Leases						Operating Leases						Finance Leases
ROU assets, net
Equipment, real estate and other			$	29					$	38					$	33					$	36
Pipelines and storage			22						23						25						14
Railcars			16						—						17						—
Lease liability
Equipment, real estate and other			$	26					$	36					$	30					$	33
Pipelines and storage			22						32						25						25
Railcars			16						—						16						—

Lease Expense Summary for the Three and Nine Months Ended September 30, 2025 and 2024

We recognize short-term and operating lease expense within Direct operating expenses (exclusive of depreciation and amortization) and Cost of materials and other, and finance lease expense within Depreciation and amortization, on a straight-

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

line basis over the lease term. For the three and nine months ended September 30, 2025 and 2024, we recognized lease expense comprised of the following components:

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions)			2025						2024						2025						2024
Operating lease expense			$	5					$	5					$	16					$	14
Finance lease expense:
Amortization of ROU asset			2						1						6						4
Interest expense on lease liability			2						1						4						3
Short-term lease expense			4						3						10						9

(6) Other Current Liabilities

Other current liabilities were as follows:

(in millions)			September 30, 2025						December 31, 2024
Accrued RFS obligation (1)			$	93					$	323
Personnel accruals			52						54
Accrued taxes other than income taxes			44						45
Deferred revenue			36						51
Share-based compensation			31						8
Accrued interest			21						34
Current portion of operating lease liabilities			16						16
Current portion of long-term debt and finance lease obligations			14						12
Other accrued expenses and liabilities			11						17
Total other current liabilities			$	318					$	560

(1)Changes in the RFS liability include adjustments to reflect the SREs affirmed by the EPA’s decision in August 2025 in the amount of $488 million for the three and nine months ended September 30, 2025. Refer to Note 12 (“Commitments and Contingencies”) for further discussion.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

(7) Long-Term Debt and Finance Lease Obligations

Long-term debt and finance lease obligations 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
Finance lease obligations, net of current portion			2						—
Unamortized debt issuance costs			(3)						(4)
Total CVR Energy debt			999						996
Petroleum Segment:
Term loan			229						322
Finance lease obligations, net of current portion			35						29
Unamortized debt discount and debt issuance costs			(5)						(8)
Total Petroleum Segment finance lease obligations, net of current portion			259						343
Nitrogen Fertilizer Segment:
6.125% Senior Secured Notes, due June 2028			550						550
Finance lease obligations, net of current portion			21						20
Unamortized debt issuance costs			(2)						(2)
Total Nitrogen Fertilizer Segment debt and finance lease obligations, net of current portion			569						568
Total long-term debt and finance lease obligations, net of current portion			1,827						1,907
Current portion of long-term debt and finance lease obligations			14						12
Total long-term debt and finance lease obligations, including current portion			$	1,841					$	1,919

Credit Agreements

(in millions)			Total Available Borrowing Capacity						Amount Borrowed as of September 30, 2025						Outstanding Letters of Credit						Available Capacity as of September 30, 2025						Maturity Date
Petroleum Segment
CVR Energy’s Amended and Restated ABL Credit Agreement (“CVR Energy ABL”)			$	341					$	—					$	25					$	316					June 30, 2027
Nitrogen Fertilizer Segment:
CVR Partners’ Credit Agreement (“CVR Partners ABL”)			$	50					$	—					$	—					$	50					September 26, 2028

Petroleum Segment

Term Loan - On June 30, 2025, certain of the Company’s subsidiaries (the “Term Loan Borrowers”) prepaid $70 million in principal of the senior secured term loan facility (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. As a result of these transactions, the Company recognized in Interest expense, net a loss on extinguishment of debt of approximately $1 million and less than $1 million in the second and third quarter of 2025, respectively, related to the write-off of unamortized discount and deferred financing costs.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Covenant Compliance

The Company and its subsidiaries were in compliance with all covenants under their respective debt instruments as of September 30, 2025.

(8) Revenue

The following table presents the Company’s revenue disaggregated by major product, which include a reconciliation of the disaggregated revenue by the Company’s reportable segments:

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions)			2025						2024						2025						2024
Petroleum Segment:
Gasoline			$	856					$	882					$	2,283					$	2,713
Distillates (1)			794						698						1,984						2,200
Crude oil sales			29						26						361						111
Other revenue			57						39						141						131
Total Petroleum Segment revenue			1,736						1,645						4,769						5,155
Renewables Segment:
Renewable diesel			39						37						92						73
Renewable fuel credits			5						27						17						50
Total Renewables Segment revenue			44						64						109						123
Nitrogen Fertilizer Segment:
Ammonia			25						25						93						84
UAN			114						77						310						241
Urea Products			10						8						29						22
Other revenue			15						14						42						38
Total Nitrogen Fertilizer Segment revenue			164						124						474						385
Total revenue			$	1,944					$	1,833					$	5,352					$	5,663

(1)Distillates consist primarily of diesel fuel, kerosene, and jet fuel.

Remaining Performance Obligations

The Company has spot and term contracts with customers and the transaction prices are either fixed or based on market indices (variable consideration). The Company does not disclose remaining performance obligations for contracts that have terms of one year or less and for contracts where the variable consideration was entirely allocated to an unsatisfied performance obligation. As of September 30, 2025, these contracts have a remaining duration of less than one year.

As of September 30, 2025, the Nitrogen Fertilizer Segment had approximately $5 million of remaining performance obligations for contracts with an original expected duration of more than one year. The Nitrogen Fertilizer Segment expects to recognize $2 million of these performance obligations as revenue by the end of 2025, $3 million during 2026, and the remaining balance in 2027.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Contract Balances

The following table provides the balance sheet location and amounts of deferred revenue from contracts with customers for the Nitrogen Fertilizer Segment:

Contract Balance Type						Balance Sheet Location						September 30, 2025						December 31, 2024
Deferred revenue						Other current liabilities						$	36					$	51
Long-term deferred revenue						Other long-term liabilities						22						27

During the nine months ended September 30, 2025 and 2024, the Company recognized revenue of $49 million and $14 million, respectively, that was included in the deferred revenue balances as of December 31, 2024 and December 31, 2023, respectively.

(9) Derivative Financial Instruments

The following outlines the net notional buy (sell) position of our commodity derivative instruments held as of September 30, 2025 and December 31, 2024:

(in thousands of barrels)			Commodity						September 30, 2025						December 31, 2024
Forwards			Crude						(209)						(11)
Swaps			NYMEX Diesel Cracks (1)						(4,800)						(63)
Swaps			NYMEX RBOB Cracks						(375)						—
Futures			Crude						(50)						—
Futures			ULSD						(25)						(80)
Futures			RBOB						(15)						—
Futures			Soybean						(79)						79

(1)As of September 30, 2025, the Company held offsetting NYMEX Diesel Crack commodity buy and sell positions of approximately 1.8 million barrels.

The following outlines the balances of our commodity derivative instruments after the effects of contract netting and allocation of collateral and their classifications on our Condensed Consolidated Balance Sheets. Refer to Note 10 (“Fair Value Measurements”) for the gross amounts of the commodity derivative instruments (before the effects of contract netting and allocation of collateral):

			September 30, 2025												December 31, 2024
(in millions)			Assets						Liabilities						Assets						Liabilities
Other current assets			$	3					$	—					$	4					$	—
Other current liabilities			—						6						—						—

The following table represents CVR Energy’s incurred realized and unrealized net gains from derivative activities, recorded in Cost of materials and other on the Condensed Consolidated Statements of Operations:

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions)			2025						2024						2025						2024
Commodity derivative instruments			$	—					$	2					$	19					$	7

CVR Energy has certain derivative instruments that contain credit risk-related contingent provisions associated with our credit ratings. If our credit rating were to be downgraded, it would allow the counterparty to require us to post collateral or to request immediate, full settlement of derivative instruments in liability positions. As of September 30, 2025, there were $6 million of derivative liabilities with credit risk-related contingent provisions, for which no collateral has been posted.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

(10) Fair Value Measurements

Assets and liabilities measured at fair value on a recurring basis

The following tables set forth information about the assets and liabilities measured at fair value on a recurring basis, by input level, as of September 30, 2025 and December 31, 2024. Such amounts are presented on a gross basis, before the effects of netting and allocation of collateral. The Company elected to offset the fair value amounts recognized for derivative assets and liabilities executed with the same counterparty under a master netting arrangement, including fair value amounts recognized for the right to reclaim or the obligation to return cash collateral.

			September 30, 2025
			Fair Value Hierarchy																		Total gross fair value						Contract netting						Collateral netting (1)						Net value
(in millions)			Level 1						Level 2						Level 3
Assets
Commodity derivative instruments			$	—					$	18					$	—					$	18					$	(15)					$	—					$	3
Liabilities
Commodity derivative instruments			—						21						—						21						(15)						—						6
RFS			—						93						—						93						—						—						93

			December 31, 2024
			Fair Value Hierarchy																		Total gross fair value						Contract netting						Collateral netting (1)						Net value
(in millions)			Level 1						Level 2						Level 3
Assets
Commodity derivative instruments			$	—					$	17					$	—					$	17					$	(13)					$	—					$	4
Liabilities
Commodity derivative instruments			—						13						—						13						(13)						—						—
RFS			—						323						—						323						—						—						323

(1)At September 30, 2025 and December 31, 2024, the Company had $8 million and $3 million of collateral under master netting arrangements not offset against the derivatives within Other current assets on the Condensed Consolidated Balance Sheets, respectively, primarily related to initial margin requirements.

The Company’s commodity derivative contracts consist of exchange traded futures, commodity price swaps, and sale and purchase forwards that are measured at fair value using a market approach based on available broker quoted market prices of identical or similar instruments. Similarly, RFS obligations are measured at fair value using a market approach based on available broker quoted market renewable fuel credits, known as renewable identification numbers (“RINs”), spot prices for each specific or closest vintage year.

The Company had no transfers of assets or liabilities between any of the above levels during the nine months ended September 30, 2025 and year ended December 31, 2024.

Assets and liabilities not required to be measured at fair value

CVR Energy holds cash equivalents which consist primarily of bank time deposits with maturities of 90 days or less. Cash and cash equivalents and reserved funds had carrying and fair values of $670 million and $987 million at September 30, 2025 and December 31, 2024, respectively, and are classified as Level 1 in the fair value hierarchy.

Long-term debt of $1.8 billion and $1.9 billion at September 30, 2025 and December 31, 2024, respectively, had estimated fair values of $1.6 billion and $1.5 billion, respectively, and are classified as Level 2 in the fair value hierarchy.

Other short-term financial assets and liabilities, which consist of restricted cash, accounts receivable, accounts payable, and operating and finance lease obligations, are carried at cost on the Condensed Consolidated Balance Sheets as of September 30, 2025 and December 31, 2024 and approximate their estimated fair values.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

(11) Share-Based Compensation

A summary of compensation expense during the three and nine months ended September 30, 2025 and 2024 is presented below:

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions)			2025						2024						2025						2024
CVR Partners - Phantom Unit Awards			$	2					$	1					$	4					$	3
Incentive Unit Awards			17						2						33						10
Total share-based compensation expense			$	19					$	3					$	37					$	13

(12) Commitments and Contingencies

In the ordinary course of business, the Company may become party to lawsuits, administrative proceedings, and governmental investigations, including environmental, regulatory, and other matters. The outcome of these matters cannot always be predicted accurately, but the Company accrues liabilities for these matters if the Company has determined that it is probable a loss has been incurred and the loss can be reasonably estimated. Except as discussed below, there have been no material changes in the Company’s commitments and contingencies from those disclosed in the 2024 Form 10-K. Certain recent developments are also discussed below.

Crude Oil Supply Agreement

The Petroleum Segment has a crude oil supply agreement with Gunvor USA LLC (“Gunvor”), which commenced on January 1, 2024 (as amended, the “Gunvor Crude Oil Supply Agreement”), pursuant to which Gunvor supplies the Petroleum Segment with certain crude oil and intermediation logistics helping to reduce the amount of inventory held at certain locations and mitigate crude oil pricing risk. Volumes contracted under this agreement, as a percentage of the total crude oil purchases (in barrels), were approximately 32% and 21% for the three months ended September 30, 2025 and 2024, respectively, and 18% and 21% for the nine months ended September 30, 2025 and 2024, respectively. On July 29, 2025, the Gunvor Crude Oil Supply Agreement was amended to update certain commercial terms and extend its term through January 31, 2029, which is subject to two successive automatic one-year renewals following the expiration of the amended term in the absence of 180 days’ notice of termination.

45Q Transaction

Under the agreements entered into in connection with the 45Q Transaction, the Company’s indirect subsidiary, Coffeyville Resources Nitrogen Fertilizer, LLC (“CRNF”), is obligated to meet certain minimum quantities of carbon oxide supply each year during the term of the agreement and is subject to fees of up to $15 million per year (reduced pro rata for partial years) to the unaffiliated third-party investors, subject to an overall $45 million cap, if these minimum quantities are not delivered. CVR Partners issued a guarantee to the unaffiliated third-party investors and certain of their affiliates involved in the 45Q Transaction of the payment and performance obligations of CRNF and CVR-CapturePoint Parent, LLC (“CVRP JV”), which include the aforementioned fees. This guarantee has no impacts on the accounting records of CVR Partners unless the parties fail to comply with the terms of the 45Q Transaction contracts.

Renewable Fuel Standard

Coffeyville Resources Refining & Marketing, LLC (“CRRM”) and WRC (together with CRRM, the “obligated-party subsidiaries”) are subject to the RFS implemented by the EPA, which, absent any exemption or waiver, requires obligated parties to blend a certain amount of renewable fuels, called a Renewable Volume Obligation (“RVO”), into their transportation fuels or purchase RINs, in lieu of blending. The Petroleum Segment’s obligated-party subsidiaries are not able to blend the majority of their transportation fuels with renewable fuels and, unless their RFS obligations are waived or exempted, must either purchase RINs from third parties, including their affiliate, or obtain waiver credits for cellulosic biofuels in order to comply with the RFS.

As previously announced, on August 22, 2025, the EPA issued a decision document to the Company’s subsidiary, WRC, affirming the validity of its previous grant of WRC’s petitions for small refinery hardship relief under the RFS for WRC’s 2017

and 2018 compliance periods, 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. WRC timely complied with its RFS obligations for the 2023 and prior compliance periods by the October 1, 2025 deadline set forth in the 2025 SRE Decision. In July 2025, the EPA’s partial waiver of the 2024 cellulosic biofuel volume requirement was published in the Federal Register, making the RFS compliance reporting deadline for all obligated parties for the 2024 compliance period December 1, 2025.

Taking into account the 2025 SRE Decision, the Company’s obligated-party subsidiaries recognized, net of RIN sales, a benefit of $417 million and an expense of $86 million for the three months ended September 30, 2025 and 2024, respectively, and a benefit of $171 million and an expense of $65 million for the nine months ended September 30, 2025 and 2024, respectively, for their compliance with the RFS. The costs to comply with the RFS obligation through purchasing of RINs not otherwise reduced by blending of ethanol, biodiesel, or renewable diesel are included within Cost of materials and other in the Condensed Consolidated Statements of Operations. At each reporting period, to the extent RINs purchased and generated through blending are less than the RFS obligation (excluding the impact of exemptions or waivers to which the Company may be entitled), the remaining position is valued using RIN market prices at period end for each specific or closest vintage year.

As of September 30, 2025 and December 31, 2024, the Company’s obligated-party subsidiaries’ RFS positions were approximately $93 million and $323 million, respectively, and are recorded in Other current liabilities in the Condensed Consolidated Balance Sheets.

Litigation

Renewable Fuel Standard – WRC’s previous legal challenges against the EPA relating to WRC’s SRE petitions for its historical compliance periods were effectively mooted by the 2025 SRE Decision. On October 27, 2025, WRC filed in the United States Circuit Court of Appeals for the District of Columbia Circuit (the “DC Circuit”) a petition for review of the 2025 EPA Decision with respect to WRC’s 2020, 2022, 2023 and 2024 SREs, primarily intended to preserve WRC’s rights to challenge scoring and decisions relating to WRC’s future SRE petitions; similar petitions for review of the 2025 SRE Decision were filed by multiple other small refineries. Also in August 2025, the EPA requested additional information from WRC relating to its SRE petition for the 2025 compliance period. WRC submitted its SRE petition for the 2025 compliance period in July 2025, ruling on which WRC believes was due from the EPA in October 2025. WRC is currently evaluating the EPA’s request and any actions WRC may take relating to its 2025 SRE petition. As these matters are in their earliest stages, the Company cannot yet determine the impact thereof, or any actions of the EPA relating thereto, could have on WRC’s past, current, and future obligations under the RFS or the Company’s financial position, results of operations, or cash flows, which could be material.

Guaranty Dispute – In October 2025, a subsidiary of CVR Energy entered into a stipulation with Exxon Mobil Corporation (“XOM”) in connection with the lawsuit it filed in the Superior Court of the State of Delaware disputing the validity of an alleged guaranty claimed by XOM to have been issued in its favor in 1993 extending all deadlines under the litigation until December 1, 2025. As this matter remains in its early stages, the Company cannot yet determine whether its outcome will have a material adverse impact on the Company’s financial position, results of operations, or cash flows.

Wynnewood 2023 Fire Claim - In August 2025, plaintiffs in a lawsuit filed by three contractor employees alleging personal injuries arising from the 2023 fire at the Wynnewood Refinery issued a settlement demand in the amount of $60 million. The Company disputes plaintiffs’ claims and has tendered defense and indemnity of the lawsuit to certain of its contractors and carriers. Trial is currently set for January 6, 2026. While the Company is vigorously defending itself, if this matter is ultimately concluded in a manner adverse to the Company, it could have a material effect on the Company’s financial position, results of operations, or cash flows.

CRNF Ammonia Release - In October 2025, a lawsuit was filed against CVR Energy, Inc. in the 268th Judicial District Court of Fort Bend County, Texas alleging damages arising from an ammonia release that occurred at the Coffeyville Fertilizer Facility in October 2025, following which multiple individuals were transported to hospitals for evaluation and treatment. As this matter is in its earliest stages, the Company cannot yet determine whether this incident could have a material adverse effect on the Company’s financial position, results of operations, or cash flows.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

(13) Business Segments

CVR Energy’s revenues are primarily derived from the three reportable segments: Petroleum, Renewables, and Nitrogen Fertilizer, which were determined based on the management approach, reflecting the internal reporting used by the Chief Operating Decision Maker (“CODM”), the Company’s Chief Executive Officer, to evaluate performance and make strategic decisions.

•Petroleum includes the refining and marketing of high value transportation fuels which consist of gasoline, diesel, jet fuel, and distillates. The Petroleum Segment also includes activities related to crude gathering and logistics that support the refinery operations.

•Renewables includes the refining of renewable feedstocks, such as soybean oil, corn oil, and other renewable feedstocks, into renewable diesel and marketing of renewables products.

•Nitrogen Fertilizer includes the production and sales of nitrogen fertilizer products, primarily in the form of ammonia and UAN, for the farming industry.

The CODM evaluates the performance of each reportable segment and decides how to allocate resources, as applicable, based on segment operating income (loss) which includes the revenue and expenses that are directly attributable to each segment, as well as the total assets per segment. The CODM uses operating income (loss) and total assets by segment to assess the results generated by each reportable segment and to decide, as applicable, whether to recommend that the Board reinvest profits into the reportable segments, if at all, or pay dividends. Operating income (loss) by segment is also used to analyze performance against the budget and the Company’s competitors.

The other amounts reflect intercompany transactions, corporate cash and cash equivalents, income tax activities, and other corporate activities that are not allocated or aggregated to the reportable segments.

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, this decision is expected to result in changes to the Company’s reportable segments, subject to completion of the operational transition and related financial reporting assessments. As of September 30, 2025, no changes have been made to the Company’s reportable segments, and there were no impacts on the segment results presented as of and for the three and nine months ended September 30, 2025. Refer to Note 4 (“Long-Term Assets”) for further discussion.

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

The following tables present the operating results and capital expenditures information by segment, the reconciliations to the consolidated net profit (loss), and other required disclosures:

			Three Months Ended September 30, 2025
(in millions)			Petroleum Segment						Renewables Segment						Nitrogen Fertilizer Segment						Other / Eliminations						Consolidated
Third-party sales			$	1,736					$	44					$	164					$	—					$	1,944
Inter-segment fees and sales			3						55						—						(58)						—
Net sales			1,739						99						164						(58)						1,944
Less:
Cost of materials and other			1,031						99						25						(59)						1,096
Direct operating expenses (exclusive of depreciation and amortization)			113						9						58						(1)						179
Selling, general and administrative expenses (exclusive of depreciation and amortization)			24						4						9						5						42
Depreciation and amortization			52						36						20						3						111
Loss on asset disposals			1						2						1						—						4
Operating income (loss)			$	518					$	(51)					$	51					$	(6)					$	512
Reconciliation of Operating income (loss) to Net income:
Interest expense, net																											$	(25)
Other income, net																											2
Income tax expense																											(88)
Net income																											$	401
Other segment disclosures:
Interest income			$	4					$	—					$	1					$	2					$	7
Interest expense			(4)						—						(9)						(19)						(32)
Capital expenditures (1)			25						1						14						—						40

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

			Three Months Ended September 30, 2024
(in millions)			Petroleum Segment						Renewables Segment						Nitrogen Fertilizer Segment						Other / Eliminations						Consolidated
Third-party sales			$	1,645					$	64					$	124					$	—					$	1,833
Inter-segment fees and sales			3						35						1						(39)						—
Net sales			1,648						99						125						(39)						1,833
Less:
Cost of materials and other			1,604						78						26						(42)						1,666
Direct operating expenses (exclusive of depreciation and amortization)			100						9						56						—						165
Selling, general and administrative expenses (exclusive of depreciation and amortization)			23						3						7						7						40
Depreciation and amortization			40						6						25						4						75
Operating (loss) income			$	(119)					$	3					$	11					$	(8)					$	(113)
Reconciliation of Operating (loss) income to Net loss:
Interest expense, net																											$	(18)
Other income, net																											3
Income tax benefit																											6
Net loss																											$	(122)
Other segment disclosures:
Interest income			$	5					$	—					$	1					$	3					$	9
Interest expense			—						—						(8)						(19)						(27)
Capital expenditures (1)			28						—						10						1						39

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

			Nine Months Ended September 30, 2025
(in millions)			Petroleum Segment						Renewables Segment						Nitrogen Fertilizer Segment						Other / Eliminations						Consolidated
Third-party sales			$	4,769					$	109					$	474					$	—					$	5,352
Inter-segment fees and sales			8						131						1						(140)						—
Net sales			4,777						240						475						(140)						5,352
Less:
Cost of materials and other			4,039						219						86						(149)						4,195
Direct operating expenses (exclusive of depreciation and amortization)			306						23						173						1						503
Selling, general and administrative expenses (exclusive of depreciation and amortization)			65						9						24						17						115
Depreciation and amortization			142						50						59						7						258
Loss on asset disposals			1						2						1						—						4
Operating income (loss)			$	224					$	(63)					$	132					$	(16)					$	277
Reconciliation of Operating income (loss) to Net income:
Interest expense, net																											$	(79)
Other income, net																											5
Income tax benefit																											3
Net income																											$	206
Other segment disclosures:
Interest income			$	14					$	1					$	4					$	5					$	24
Interest expense			(19)						—						(27)						(57)						(103)
Capital expenditures (1)			98						3						30						1						132

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NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

			Nine Months Ended September 30, 2024
(in millions)			Petroleum Segment						Renewables Segment						Nitrogen Fertilizer Segment						Other / Eliminations						Consolidated
Third-party sales			$	5,155					$	123					$	385					$	—					$	5,663
Inter-segment fees and sales			10						73						1						(84)						—
Net sales			5,165						196						386						(84)						5,663
Less:
Cost of materials and other			4,645						165						78						(92)						4,796
Direct operating expenses (exclusive of depreciation and amortization)			320						24						158						—						502
Selling, general and administrative expenses (exclusive of depreciation and amortization)			57						7						21						18						103
Depreciation and amortization			133						18						64						9						224
Loss on asset disposals			1						—						—						—						1
Operating income (loss)			$	9					$	(18)					$	65					$	(19)					$	37
Reconciliation of Operating income (loss) to Net income:
Interest expense, net																											$	(56)
Other income, net																											10
Income tax benefit																											14
Net income																											$	5
Other segment disclosures:
Interest income			$	17					$	—					$	3					$	10					$	30
Interest expense			(1)						—						(25)						(60)						(86)
Capital expenditures (1)			97						10						19						4						130

The following table summarizes the reconciliation of total assets by segment to consolidated total assets:

(in millions)			September 30, 2025						December 31, 2024
Petroleum			$	3,001					$	3,288
Renewables			393						420
Nitrogen Fertilizer			1,037						1,019
Other, including inter-segment eliminations			(439)						(464)
Total assets			$	3,992					$	4,263

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures.

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

(14) Supplemental Cash Flow Information

Cash flows related to income taxes, interest, leases, and capital and turnaround expenditures included in accounts payable were as follows:

			Nine Months Ended September 30,
(in millions)			2025						2024
Supplemental disclosures:
Cash (received, net of payments) paid, net of refunds for income taxes			$	(3)					$	60
Cash paid for interest			116						94
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases			16						14
Operating cash flows from finance leases			4						3
Financing cash flows from finance leases			7						6
Noncash investing and financing activities:
Change in capital expenditures included in accounts payable (1)			2						6
Change in turnaround expenditures included in accounts payable			(7)						(1)
ROU assets obtained in exchange for new or modified operating lease liabilities			4						14
ROU assets obtained in exchange for new or modified finance lease liabilities			14						—

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures.

(15) Related Party Transactions

Activity associated with the Company’s related party arrangements for the three and nine months ended September 30, 2025 and 2024 is summarized below:

			Three Months Ended September 30,												Nine Months Ended September 30,
(in millions)			2025						2024						2025						2024
Sales to related parties:
CVRP JV CO Contract (1)			$	1					$	1					$	2					$	2
Purchases from related parties:
Enable Joint Venture Transportation Agreement			3						3						10						9
Midway Joint Venture Agreement (2)			—						6						—						20
Payments:
Dividends (3)			—						33						—						100

(1)Sales to related parties, included in Net sales in our Condensed Consolidated Statements of Operations, consists of carbon oxide sales to a CVRP JV subsidiary.

(2)Purchases from related parties, included in Cost of materials and other in our Condensed Consolidated Statements of Operations, represent reimbursements for crude oil transportation services incurred on the crude oil pipeline connecting the refinery in Coffeyville, Kansas and the Cushing, Oklahoma oil hub (the “Midway Pipeline”) through Gunvor as the intermediary purchasing agent. On December 23, 2024, the Company sold the 50% limited liability company interest it owned in the Midway Pipeline.

(3)See below for a summary of the dividends paid to IEP during the nine months ended September 30, 2025 and year ended December 31, 2024.

Dividends to CVR Energy Stockholders

Dividends, if any, including the payment, amount and timing thereof, are determined at the discretion of the board of directors of the Company (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

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CVR ENERGY, INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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						March 11, 2024						$	0.50					$	17					$	33					$	50
2024 - 1st Quarter						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 the board of directors of CVR Partners’ general partner’s (the “UAN GP Board”) 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 Company and IEP, during 2025 and 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						August 18, 2025						3.89						25						1						15						41
Total 2025 quarterly distributions												$	7.90					$	51					$	2					$	31					$	83
2023 - 4th Quarter						March 11, 2024						$	1.68					$	11					$	—					$	7					$	18
2024 - 1st Quarter						May 20, 2024						1.92						13						—						7						20
2024 - 2nd Quarter						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, CVR Partners, upon approval by the UAN GP Board on October 29, 2025, 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.

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Item 2.  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:

Crude Oil Differentials against WTI (1)(2)

NYMEX Crack Spreads (2)

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PADD II Group 3 Product Crack

Spread and RIN Pricing (2)(3) ($/bbl)

Group 3 Product Differential against NYMEX

Products (1)(2) ($/bbl)

(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 2025 compared to the same period of 2024.

The tables below are presented by month through September 30, 2025:

Benchmark Renewable Diesel Margins (1) (2) (3)

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LCFS Credit Price and D4 RIN Market Pricing (1) Soybean Oil and LA/SF CARB Market Pricing (1)

(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.

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U.S. Plant Production of Fuel Ethanol (1) Corn and Soybean Planted Acres (2)

(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.

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The charts below show relevant market indicators for the Nitrogen Fertilizer Segment by month through September 30, 2025:

Ammonia and UAN Market Pricing (1)

Natural Gas Market Pricing (1) Pet Coke Market Pricing (1)

(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.

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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)

Operating Income (Loss) Net Income (Loss) Attributable to CVR Energy Stockholders

Earnings (Loss) per Share EBITDA (1)

(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.

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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,
(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

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Production Data			Three Months Ended September 30,												Nine Months Ended September 30,
(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
Crude utilization (1)			96.6		%				84.7		%				75.6		%				85.1		%
Light product yield (as % of crude throughput) (2)			97.5		%				98.6		%				97.6		%				99.3		%
Liquid volume yield (as % of total throughput) (3)			97.1		%				97.0		%				96.4		%				96.9		%
Distillate yield (as % of crude throughput) (4)			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.

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Petroleum Net Sales Petroleum Operating Income

Petroleum Net Income (Loss) Petroleum EBITDA (1)

(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.

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Q3 Petroleum Refining Margin (1) YTD Petroleum Refining Margin (1)

(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.

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Q3 Petroleum Direct Operating Expenses (1) YTD Petroleum Direct Operating Expenses (1)

(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.

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Petroleum Depreciation and Amortization Expense Petroleum Selling, General, and Administrative
Expenses

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,
(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
Renewable utilization (1)			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.

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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

Renewables Net (Loss) Income Renewables EBITDA (1)

(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measure shown above.

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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.

Q3 Renewables Margin (1) YTD Renewables Margin (1)

(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.

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Q3 Renewables Direct Operating Expenses (1) YTD Renewables Direct Operating Expenses (1)

(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

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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:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2025						2024						2025						2024
Ammonia utilization rate			95		%				97		%				96		%				96		%
Production volumes (thousands of tons)
Ammonia (gross produced)			208						212						621						626
Ammonia (net available for sale)			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).

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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.

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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.

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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,

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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.

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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.

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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.

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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.

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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						March 11, 2024						$	0.50					$	17					$	33					$	50
2024 - 1st Quarter						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 2025 and 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						August 18, 2025						3.89						25						1						15						41
Total 2025 quarterly distributions												$	7.90					$	51					$	2					$	31					$	83
2023 - 4th Quarter						March 11, 2024						$	1.68					$	11					$	—					$	7					$	18
2024 - 1st Quarter						May 20, 2024						1.92						13						—						7						20
2024 - 2nd Quarter						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.

Item 3.  Quantitative and Qualitative Disclosures About Market Risk

There have been no material changes to our market risks as of and for the three and nine months ended September 30, 2025, as compared to the risks discussed in Part II, Item 7A of our 2024 Form 10-K.

Item 4.  Controls and Procedures

Evaluation of Disclosure Controls and Procedures

The Company has evaluated, under the direction and with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as defined in Exchange Act Rule 13a-15(e) and 15d-15(e). Based upon this evaluation, the Company’s Chief Executive Officer and Chief Financial Officer concluded that disclosure controls and procedures were effective as of September 30, 2025.

Changes in Internal Control Over Financial Reporting

There have been no material changes in our internal controls over financial reporting required by Rule 13a-15 of the Exchange Act that occurred during the fiscal quarter ended September 30, 2025 that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1.  Legal Proceedings

See Part I, Item 1, Note 12 (“Commitments and Contingencies”) of this Report, which is incorporated by reference into this Part II, Item 1, for a description of certain litigation, legal, and administrative proceedings and environmental matters.

Item 1A. Risk Factors

There have been no material changes from the risk factors previously disclosed in Part I, Item 1A of our 2024 Form 10-K. Additional risks and uncertainties, including risks and uncertainties not presently known to us, or that we currently deem immaterial, could also have an adverse effect on our business, financial condition, and/or results of operations.

Item 5. Other Information

During the three months ended September 30, 2025, no director or officer of the Company adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement”, as each term is defined in Item 408(a) of Regulation S-K.

Item 6.  Exhibits

INDEX TO EXHIBITS
Exhibit Number						Exhibit Description
10.1*+						Amendment No 1. to Amended & Restated Crude Oil Supply Agreement, effective February 1, 2026, by and between Gunvor USA LLC and CVR Supply & Trading LLC.
10.2**^						Amendment to Employment Agreement, dated as of December 12, 2024, by and between CVR Energy, Inc. and David L. Lamp (incorporated by reference to Exhibit 10.11 to the Company’s Form 10-Q filed on July 31, 2025).
10.3**^						Employment Agreement, dated as of July 28, 2025, by and between CVR Energy, Inc. and Mark A. Pytosh (incorporated by reference to Exhibit 10.12 to the Company’s Form 10-Q filed on July 31, 2025).
31.1*						Rule 13a-14(a)/15(d)-14(a) Certification of President and Chief Executive Officer.
31.2*						Rule 13a-14(a)/15(d)-14(a) Certification of Executive Vice President, Chief Financial Officer, Treasurer and Assistant Secretary.
31.3*						Rule 13a-14(a)/15(d)-14(a) Certification of Vice President, Chief Accounting Officer and Corporate Controller.
32.1†						Section 1350 Certification of President and Chief Executive Officer, Executive Vice President, Chief Financial Officer, Treasurer and Assistant Secretary, and Vice President, Chief Accounting Officer and Corporate Controller.
101*						The following financial information for CVR Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2025 formatted Inline XBRL (“Extensible Business Reporting Language”) includes: (i) Condensed Consolidated Balance Sheets (unaudited), (ii) Condensed Consolidated Statements of Operations (unaudited), (iii) Condensed Consolidated Statement of Changes in Equity (unaudited), (iv) Condensed Consolidated Statements of Cash Flows (unaudited) and (v) the Notes to Condensed Consolidated Financial Statements (unaudited), tagged in detail.
104*						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

*			Filed herewith.
**			Previously filed.
†			Furnished herewith.
+			Certain portions of this exhibit have been redacted pursuant to Item 601(b)(10)(iv) of Regulation S-K. The Company agrees to furnish supplementally an unredacted copy of this exhibit to the SEC upon request.
^			Denotes management contract or compensatory plan or arrangement.

PLEASE NOTE: Pursuant to the rules and regulations of the SEC, we may file or incorporate by reference agreements as exhibits to the reports that we file with or furnish to the SEC. The agreements are filed to provide investors with information regarding their respective terms. The agreements are not intended to provide any other factual information about the Company,

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its business or operations. In particular, the assertions embodied in any representations, warranties and covenants contained in the agreements may be subject to qualifications with respect to knowledge and materiality different from those applicable to investors and may be qualified by information in confidential disclosure schedules not included with the exhibits. These disclosure schedules may contain information that modifies, qualifies and creates exceptions to the representations, warranties and covenants set forth in the agreements. Moreover, certain representations, warranties and covenants in the agreements may have been used for the purpose of allocating risk between the parties, rather than establishing matters as facts. In addition, information concerning the subject matter of the representations, warranties and covenants may have changed after the date of the respective agreement, which subsequent information may or may not be fully reflected in the Company’s public disclosures. Accordingly, investors should not rely on the representations, warranties and covenants in the agreements as characterizations of the actual state of facts about the Company, its business or operations on the date hereof.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

						CVR Energy, Inc.
October 30, 2025						By:			/s/ Dane J. Neumann
									Executive Vice President, Chief Financial Officer, Treasurer and Assistant Secretary
									(Principal Financial Officer)
October 30, 2025						By:			/s/ Jeffrey D. Conaway
									Vice President, Chief Accounting Officer and Corporate Controller
									(Principal Accounting Officer)

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FAQ

How did CVR Energy (CVI) perform in Q3 2025?

Net income was $401 million versus a $122 million loss in Q3 2024; operating income reached $512 million on net sales of $1,944 million.

What was the impact of the EPA’s SRE decision on CVI?

The decision reduced obligations by about $488 million and led to a Q3 $417 million RFS compliance benefit; the RFS position was $93 million at quarter-end.

How did each segment contribute in Q3 2025?

Petroleum operating income was $518 million; Renewables had a $51 million operating loss; Nitrogen Fertilizer generated $51 million.

What changes are planned for the Wynnewood renewable diesel unit?

CVR plans to revert the unit to hydrocarbon service in December 2025, recording $31 million accelerated depreciation and a $3 million project write-off in Q3.

What is CVR Energy’s liquidity and debt position?

Cash was $670 million. The company prepaid $90 million on its term loan in Q2–Q3; total long-term debt and finance leases were $1,841 million including current portion.

When is the 2024 RFS compliance reporting deadline?

The deadline for the 2024 compliance period is December 1, 2025.