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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

☒ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2025

☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 001-42172

Calumet, Inc.

(Exact Name of Registrant as Specified in Its Charter)



Delaware		36-5098520
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification Number)
1060 N Capitol Ave, Suite 6-401
Indianapolis, IN		46204
(Address of Principal Executive Offices)		(Zip Code)

(317) 328-5660

(Registrant’s Telephone Number, Including Area Code)

None

(Former Name, Former Address and Former Fiscal Year, If Changed Since Last Report)

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, par value $0.01 per share	CLMT	The Nasdaq Stock Market LLC

SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:

NONE.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☒ Yes ☐ No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ☐ Yes ☒ No

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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ☐

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

The aggregate market value of the common stock held by non-affiliates of the registrant was approximately $1.4 billion on June 30, 2025, based on $15.76 per share, the closing price of the common stock as reported on the Nasdaq Global Select Market on such date.

On February 27, 2026, there were 86,776,552 common shares outstanding.

Table of Contents

DOCUMENTS INCORPORATED BY REFERENCE

Portions of our definitive proxy statement for the 2026 annual meeting of stockholders to be filed pursuant to Regulation 14A within 120 days after the fiscal year end of December 31, 2025 are incorporated by reference into Part III of this Report.

Table of Contents

CALUMET, INC.

FORM 10-K — 2025 ANNUAL REPORT

Table of Contents


		Page
PART I
Items 1 and 2.	Business and Properties	5
Item 1A.	Risk Factors	29
Item 1B.	Unresolved Staff Comments	51
Item 1C.	Cybersecurity	51
Item 3.	Legal Proceedings	52
Item 4.	Mine Safety Disclosures	52

PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	53
Item 6.	[Reserved]	53
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	54
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	77
Item 8.	Financial Statements and Supplementary Data	79
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	133
Item 9A.	Controls and Procedures	133
Item 9B.	Other Information	135
Item 9C.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	135

PART III
Item 10.	Directors, Executive Officers and Corporate Governance	136
Item 11.	Executive and Director Compensation	137
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	137
Item 13.	Certain Relationships and Related Transactions and Director Independence	137
Item 14.	Principal Accounting Fees and Services	138

PART IV
Item 15.	Exhibits	139
Item 16.	Form 10-K Summary	145

Table of Contents

FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10-K (this “Annual Report”) includes certain “forward-looking statements.” These statements can be identified by the use of forward-looking terminology including “will,” “may,” “intend,” “believe,” “expect,” “outlook,” “anticipate,” “estimate,” “continue,” “plan,” “should,” “could,” “would,” or other similar words. The statements regarding (i) demand for finished products in markets we serve; (ii) estimated capital expenditures as a result of required audits or required operational changes or other environmental and regulatory liabilities; (iii) our anticipated levels of, use and effectiveness of derivatives to mitigate our exposure to crude oil price changes, natural gas price changes and fuel products price changes; (iv) estimated costs of complying with the U.S. Environmental Protection Agency’s (“EPA”) Renewable Fuel Standard (“RFS”), including the prices paid for Renewable Identification Numbers (“RINs”) and the amount of RINs we may be required to purchase in any given compliance year, and the outcome of any litigation concerning our existing small refinery exemption (“SRE”) petitions; (v) our ability to monetize federal clean fuel production tax credits (“CFPCs”) under Section 45Z of the Internal Revenue Code and the price we expect to receive for CFPCs; (vi) our ability to meet our financial commitments, debt service obligations, debt instrument covenants, contingencies and anticipated capital expenditures; (vii) our access to capital to fund capital expenditures and our working capital needs and our ability to obtain debt or equity financing on satisfactory terms; (viii) our access to inventory financing under our supply and offtake agreements; (ix) the effect, impact, potential duration or other implications of supply chain disruptions and global energy shortages on our business and operations; (x) general economic and political conditions, including inflationary pressures, changes in global trade policy and tariffs, instability in financial institutions, the shutdown of the U.S. federal government, general economic slowdown or a recession, political tensions, conflicts and war (such as the ongoing conflicts in Ukraine, Venezuela, and the Middle East and their regional and global ramifications); (xi) the future effectiveness of our information technology systems to further enhance operating efficiencies and provide more effective management of our business operations; (xii) our expectation regarding our business outlook with respect to the Montana Renewables business; (xiii) an ability to maintain an effective system of internal controls; (xiv) the expected benefits of the Conversion (as defined herein) to us and our stockholders; (xv) our expectation that the DOE Facility (as defined herein) will enable MRL (as defined herein) to complete the MaxSAF^TM construction on time and on budget; and (xvi) our ability to maintain or improve our carbon intensity at our MRL facility, as well as other matters discussed in this Annual Report that are not purely historical data, are forward-looking statements. These forward-looking statements are based on our expectations and beliefs as of the date hereof concerning future developments and their potential effect on us. While management believes that these forward-looking statements are reasonable as and when made, there can be no assurance that future developments affecting us will be those that we anticipate. All comments concerning our current expectations for future sales and operating results are based on our forecasts for our existing operations and do not include the potential impact of any future acquisition or disposition transactions. Our forward-looking statements involve significant risks and uncertainties (some of which are beyond our control) and assumptions that could cause actual results to differ materially from our historical experience and our present expectations or projections. Known material factors that could cause our actual results to differ from those in the forward-looking statements are those described in Part I, Item 1A “Risk Factors” of this Annual Report. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

References in this Annual Report to “Calumet,” “the Company,” “we,” “our,” “us” or like terms refer to (i) Calumet Specialty Products Partners, L.P. (the “Partnership”) and its subsidiaries before the completion of the Conversion and (ii) Calumet, Inc. and its subsidiaries as of the completion of the Conversion and thereafter. References in this Annual Report to “the General Partner” refer to Calumet GP, LLC, the general partner of the Partnership.

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SUMMARY OF RISK FACTORS

An investment in our common shares involves a significant degree of risk. Below is a summary of certain risk factors that you should consider in evaluating us and our common shares. However, this list is not exhaustive. Before you invest in our common shares, you should carefully consider the risk factors discussed or referenced below and under Item 1A. “Risk Factors” in this Annual Report on Form 10-K. If any of the risks discussed below and under Item 1A. “Risk Factors” were actually to occur, our business, financial position or results of operations could be materially adversely affected.

Risks Related to Our Business

●

Our business depends on supply and demand fundamentals, which can be adversely affected by numerous macroeconomic factors outside of our control.

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Our business has exposure to some commodities which are volatile, and a reduction in our margins will adversely affect the amount of cash we will have available to operate our business and for payments of our debt obligations.

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Our hedging activities may not be effective in reducing our exposure to commodity price risk and may reduce our earnings, profitability and cash flows.

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We depend on certain key suppliers and third-party pipelines for transportation of feedstocks and products, and if these suppliers or pipelines become unavailable to us, our revenues and cash available for payment of our debt obligations could decline.

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The price volatility of utility services may result in decreases in our earnings, profitability and cash flows.

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Our facilities incur operating hazards, and the potential limits on insurance coverage could expose us to potentially significant liability costs.

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An impairment of our long-lived assets or goodwill could reduce our earnings or negatively impact our financial condition and results of operations.

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Competition in our industries is intense, and an increase in competition in the markets in which we sell our products could adversely affect our earnings and profitability.

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We depend on unionized labor for the operation of many of our facilities. Any work stoppages or labor disturbances at these facilities could disrupt our business and negatively impact our financial condition and results of operations.

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Our method of valuing inventory may result in decreases in net income.

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Our arrangement with J. Aron (as defined herein) exposes us to J. Aron-related credit and performance risk as well as potential refinancing risks.

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We have a substantial amount of indebtedness, which may adversely affect our cash flow and our ability to operate our business.

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Our financing arrangements contain operating and financial provisions that restrict our business and financing activities.

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A change of control could result in us facing substantial repayment obligations under our revolving credit facility, our senior notes, our secured hedge agreements, and our Supply and Offtake Agreement (as defined below).

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We must make substantial capital expenditures for our facilities to maintain their reliability and efficiency.

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We may incur significant environmental costs and liabilities in the operation of our refineries, facilities, terminals and related facilities.

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●

We are subject to compliance with stringent environmental and occupational health and safety laws and regulations.

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The availability and cost of renewable identification numbers and results of litigation related to our SRE petitions could have a material adverse effect on our results of operations and financial condition and our ability to make payments on our debt obligations.

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Our and our customers’ operations are subject to risks arising out of the threat of climate change, including operational, regulatory, political, litigation and financial risks, which could result in increased operating and capital costs for our customers and reduced demand for the products and services we provide.

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We could incur substantial costs or disruptions in our business if we cannot obtain or maintain necessary permits and authorizations or otherwise comply with occupational, environmental and other laws and regulations.

Risks Related to Montana Renewables

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If there is not sufficient demand for renewable energy, if renewable energy markets do not develop or take longer to develop than we anticipate, or if we do not realize the expected SAF premium we may be unable to achieve our investment objectives for Montana Renewables, LLC (“MRL”).

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Montana Renewables is subject to a number of statutes and regulations that could have a material adverse effect on Montana Renewables’ operations.

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Montana Renewables is subject to numerous operating risks, which could materially adversely impact our results of operations and financial conditions.

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A significant component of our product margin consists of a variety of government subsidies, incentives and mandates.

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Transactions between the Company and MRL present possible conflicts of interest that could have an adverse effect on the Company if they are not managed appropriately.

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Increases to the cost of transportation services or equipment related to our feedstock materials and renewable transportation fuels could materially and adversely affect our sales revenues and cost of operations.

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The production of renewable fuels is a growing industry, and we are expecting to encounter significant competition in the marketplace.

Risks Related to Our Common Stock

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The price of our common stock may experience volatility.

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Our amended and restated certificate of incorporation and amended and restated bylaws contain provisions that may make it more difficult for a third party to acquire control of us.

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The value of our common stock may be diluted by future equity issuances (including upon the exercise of the outstanding warrants), and shares eligible for future sale may have adverse effects on our share price.

Risks Related to Tax Matters

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We are subject to risks arising from compliance with and changes in tax laws.

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We are currently unable to fully utilize the clean fuel production tax credits (“CFPCs”) that we generate, and as such, we are exposed to fluctuations in the prices of CFPCs and the potential unavailability of parties willing to purchase CFPCs.

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PART I

Items 1 and 2. Business and Properties

Overview

We manufacture, formulate and market a diversified slate of specialty branded products and renewable fuels to customers across a broad range of consumer-facing and industrial markets. We are headquartered in Indianapolis, Indiana and operate twelve facilities throughout North America. Our operations are managed using the following reportable segments: Specialty Products and Solutions; Performance Brands; Montana/Renewables; and Corporate. In our Specialty Products and Solutions segment, we manufacture and market a wide variety of solvents, waxes, customized lubricating oils, white oils, petrolatums, gels, esters, and other products. Our specialty products are sold to domestic and international customers who purchase them primarily as raw material components for consumer-facing and industrial products. In our Performance Brands segment, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our Montana/Renewables segment is comprised of two facilities — renewable fuels and specialty asphalt. At our Montana Renewables facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel (“SAF”), and renewable naphtha that are distributed into renewable markets in the western half of North America. At our Montana specialty asphalt facility, we process Canadian crude oil into conventional gasoline, diesel, jet fuel and specialty grades of asphalt, with production sized to serve local markets. Our Corporate segment primarily consists of general and administrative expenses not allocated to the Specialty Products and Solutions, Performance Brands or Montana/Renewables segments.

Corporate Conversion

On July 10, 2024, Calumet, Inc., a Delaware corporation (the “Company” or “Calumet”), completed the conversion transaction contemplated by the Conversion Agreement, dated as of February 9, 2024 (as amended, the “Conversion Agreement”), by and among the Company, Calumet Specialty Products Partners, L.P. (the “Partnership”), the General Partner, Calumet Merger Sub I LLC (“Merger Sub I”), Calumet Merger Sub II LLC (“Merger Sub II”) and the other parties thereto, including The Heritage Group (the “Sponsor Parties”). Pursuant to the Conversion Agreement, (a) Merger Sub II merged with and into the Partnership, with the Partnership continuing as the surviving entity and a wholly owned subsidiary of the Company, and all of the common units were exchanged into the right to receive an equal number of shares of common stock, par value $0.01 per share, of the Company (“Common Stock”) and (b) Merger Sub I merged with and into the General Partner, with the General Partner continuing as the surviving entity and a wholly owned subsidiary of the Company, and all outstanding equity interests of the General Partner (1,640,583 general partner units) were exchanged into the right to receive an aggregate of 5,500,000 shares of Common Stock and 2,000,000 warrants to purchase common stock at an exercise price of $20.00 per share (subject to adjustment) on or prior to July 10, 2027 (such transactions, the “Conversion”).

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Our Assets

Our primary operating assets consist of:


						Sales Volume for the
						Year Ended December 31,
						2025 in Barrels per
Facility		Location		Year Acquired		Day (“bpd”)		Products
Calumet Packaging		Louisiana		2012		1,277		Specialty products including premium industrial and consumer synthetic lubricants, fuels and solvents
Royal Purple		Texas		2012		341		Specialty products including premium consumer synthetic lubricants
Missouri		Missouri		2012		169		Specialty products including polyol ester-based synthetic lubricants
Karns City		Pennsylvania		2008		1,694		Specialty white mineral oils, solvents, petrolatums, gelled hydrocarbons, cable fillers and natural petroleum sulfonates
Dickinson		Texas		2008		635		Specialty white mineral oils, compressor lubricants and natural petroleum sulfonates
Cotton Valley		Louisiana		1995		5,058		Specialty solvents used principally in the manufacture of paints, cleaners, automotive products and drilling fluids
Princeton		Louisiana		1990		5,091		Specialty lubricating oils, including process oils, base oils, transformer oils, refrigeration oils, and asphalt
Shreveport		Louisiana		2001		45,271		Specialty lubricating oils and waxes, gasoline, diesel, jet fuel and asphalt
Montana Specialty Asphalt (Great Falls)		Montana		2012		13,981		Specialty asphalt, gasoline, diesel, and jet fuel
Montana Renewables		Montana		2021		11,322		Renewable diesel, sustainable aviation fuel, and renewable naphtha

Storage, Distribution and Logistics Assets. We own and operate a product terminal in Burnham, Illinois with aggregate storage capacities of approximately 150,000 barrels. The Burnham terminal, as well as additional owned and leased facilities throughout the U.S., facilitate the distribution of products in the Upper Midwest, West Coast and Mid-Continent regions of the U.S. and Canada.

We also use approximately 2,300 leased railcars primarily to receive and ship crude oil and distribute our specialty and fuel products throughout the U.S. and Canada. In addition, we use approximately 350 leased railcars to source renewable feedstocks and distribute renewable fuels products into the western half of North America. In total, we have approximately 7.0 million barrels of aggregate storage capacity at our facilities and leased storage locations.

Montana Renewables. At our Montana Renewables facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel, and renewable naphtha. These renewable fuels are distributed into renewable markets in the western half of North America. In addition, we convert renewable natural gas and renewable propane to produce renewable hydrogen, which is used in our renewable refining processes.

Business Strategies

Our management team is dedicated to improving our operations by executing the following strategies:

●

Enhance Profitability of Our Existing Assets. We focus on identifying opportunities to improve our asset base, deepening our competitive advantages, and increasing our throughput, profitability, and cash flows. During the

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year ended December 31, 2025, we reduced operating costs by approximately $100.0 million in comparison to the prior year. In addition to this, we benefited from enhanced operational performance following the capital investments we made over the past few years on projects designed to improve asset reliability. As a result, our Specialty Products and Solutions segment achieved an annual production record in the current year. Further, we have streamlined the operations at our Montana Renewables facility and are planning an expansion project at the facility. This expansion project complements the project we completed in 2022, whereas we converted the historical Great Falls refinery into two independent facilities: Calumet Montana Refining (“CMR”), a 15,000 bpd specialty asphalt facility; and Montana Renewables, a 15,000 bpd renewable fuels production facility. We expanded our Montana Renewables facility in 2023, as we successfully commissioned a renewable hydrogen plant, a feedstock pre-treatment unit, and a sustainable aviation fuel unit, making Montana Renewables one of the largest SAF producers in the western hemisphere in 2024. Our MaxSAF™ expansion project is expected to deliver 120 to 150 million gallons of annualized SAF production by the second quarter of 2026. We have previously announced an attractive return on investment project at an expected cost of $20.0 million to $30.0 million. In 2024 and 2025, we continued our efforts to upgrade infrastructure at our Shreveport facility, which included projects to harden the existing assets to withstand severe weather events such as hurricanes and winter freezes. In addition to this, we installed a new pipeline connection at our Shreveport location that will provide the facility additional flexibility and access to more advantageous crude supply. Prior to 2024, we made investments in a polymerized modified asphalt unit at our Montana Specialty Asphalt facility (part of CMR) in 2022, additional wax blending assets at our Calumet Paralogics, LLC (“Paralogics”) facility in 2021, and the addition of storage capacity to increase sales of our most profitable solvents at our Cotton Valley facility in 2021. In addition, we have undertaken various small expansion and optimization projects in our Performance Brands segment over the past four years, including a new packaging line for 1.0 gallon cans of TruFuel to support growth, a new 2.1 gallon pail TruFuel line to meet the market demand for larger package sizes, and a new quart line in Porter, Texas to recognize efficiencies in packaging Bel-Ray products. We intend to continue increasing the profitability of our existing asset base through various low capital requirement measures which may include investments targeting more efficient logistics, improving the product mix of our processing units, repurposing existing assets and reducing costs through operational modernizations.

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Concentrate on Positive and Growing Cash Flows. We intend to continue to focus on operating assets and businesses that generate positive and growing cash flows. Approximately 40.6% of our continuing operations gross profit in 2025 was generated by our Specialty Products and Solutions segment, which is characterized by stable customer relationships due to our customers’ requirements for the specialized products we provide. In addition, we manage our exposure to crude oil price fluctuations in this segment by passing on incremental feedstock costs to our specialty products customers. In our Performance Brands segment, which accounted for approximately (17.9)% of our continuing operations gross profit in 2025, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our fast-growing portfolio of high-performance brands are characterized by strong customer loyalty and stable cash flows. In our Montana/Renewables segment, which accounted for approximately 83.6% of our continuing operations gross profit in 2025, we expect growth in cash flows as a result of market recovery and higher throughput.

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Develop and Expand Our Customer Relationships. Due to the specialized nature of certain of our products, the high cost of replacement and the long lead-time associated with the development and production of many of our specialty products, our customers are incentivized to continue their relationships with us. We believe that we offer a more diversified product slate to our customers than competitors do, and we also offer more technical support and bespoke services. In fiscal year 2025, we sold a range of over 1,900 specialty and fuels products to approximately 2,400 customers. We intend to continue to assist our existing customers in their efforts to expand their product offerings, as well as marketing specialty product formulations and services to new customers. By continuing to service our long-term relationships with our broad base of existing customers and by constantly targeting solutions for new customers, we seek to limit our dependence on any one portion of our customer base.

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Disciplined Approach to Strategic and Complementary Acquisitions. We do not expect to focus on large acquisitions in the near term. However, should the right opportunity develop, our senior management team is prepared to consider acquiring low-risk assets where we can enhance operations and improve profitability and product lines that will complement and expand our specialty product offerings. In the future, we intend to continue

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pursuing prudent, accretive acquisitions that will deepen our long-term competitive advantages. We intend to reduce our leverage over time and maintain a capital structure that facilitates competitive access to the capital markets.

Competitive Strengths

We believe that we are well positioned to execute our business strategies successfully based on the following competitive strengths:

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We Have Strong Relationships with a Premier Customer Base. We have long-term relationships with many of our customers and we believe that we will continue to benefit from these relationships. Many of these relationships involve lengthy approval processes or certifications that may make switching to a different supplier difficult. In fiscal year 2025, we sold our products to approximately 2,400 customers, and we are continually seeking to deepen those relationships across our broad and diversified customer base. No single customer accounted for more than 10% of our consolidated sales for any of the three years ended December 31, 2025, 2024 and 2023.

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We Offer Our Customers a Diverse Range of Specialty Products. We offer a wide range of over 1,900 specialty products. We believe that our ability to provide our customers with a more diverse selection of products than most of our competitors gives us an advantage in meeting the needs of large, strategic customers and allows us to compete in profitable niches. We believe that we are the only specialty products manufacturer in North America that produces all six of the following products: naphthenic lubricating oils, paraffinic lubricating oils, waxes, solvents, white oils and petrolatums. Our ability to produce numerous specialty products allows us to ship products between our facilities for product upgrading in order to meet customer specifications.

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We are a Leader in North America’s Energy Transition. Our MRL facility is permitted to pretreat and convert 15,000 barrels per stream day of renewable feedstocks into low-emission sustainable fuel alternatives that directly replace fossil fuel products. MRL is a leader in North America’s energy transition and one of the largest Sustainable Aviation Fuel producers in the western hemisphere. The renewable fuel products produced by MRL are distributed into renewable markets in the western half of North America.

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Our Facilities Have a Unique Combination of Flexibility, Scale and Integration. Our facilities are equipped with advanced, flexible technology that allows us to produce high-grade specialty products. For example, our integrated specialty products complex in Northwest Louisiana consists of 27 processing units and 195 million gallons of storage capacity across 400 tanks and has a wide variety of specialized hydroprocessing, dewaxing, emulsifying and distillation capabilities that allow us to meet complex, bespoke customer needs at scale providing an advantaged cost. Our acquisition of Paralogics also added new capabilities into our existing wax business value chain, adding approximately 20 million pounds of annual blending and formulating capabilities. Our facilities also enjoy the value and optionality of integration as many products can be further processed and upgraded at our own facilities.

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We Have Leading, High-Growth Brands. Our Performance Brands segment benefits from well-known high-performance premium brands in consumer, retail and industrial markets. These brands garner a premium and are well positioned for growth. Further, the majority of products in our Specialty Products and Solutions segment are marketed under well-known industrial and consumer-facing brands that are of high value in the market and in many cases were established several decades ago.

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We Have an Experienced Management Team. Our team’s extensive experience within the specialty products, commodities and renewable energy industries provides a strong foundation to build and optimize a diversified, competitively advantaged business that can succeed in various business cycles and environments.

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Potential Acquisition and Divestiture Activities

While we evaluate potential acquisitions of strategic and complementary assets that would deepen our competitive advantage, our focus has been and continues to be to de-lever our balance sheet. We evaluate our portfolio on an ongoing basis to allow an objective assessment of potential divestiture candidates that are non-core to our business and/or worth more to a buyer than to us. The combination of acquisition and divestment activities is intended to maximize our return on invested capital by creating and maintaining a portfolio of core assets that optimize our blend of feedstocks, improve our operating efficiency and cash flows, and leverage our competitive strengths. We also intend to monetize all or a portion of our equity in MRL over time.

As we optimize our asset portfolio, which may include the divestiture of certain non-core assets or all or a portion of our equity in MRL, we intend to redeploy capital into projects to develop assets that are better suited to our core specialty products business strategy and de-leverage our balance sheet.

Going forward, we intend to tailor our approach toward owning businesses with stable cash flows and growing end markets. As a result, we may pursue potential arrangements with third parties to divest certain assets to enable us to further reduce the amount of our required capital commitments and potential capital expenditures. We expect that any potential divestitures of assets will also provide us with cash to reinvest in our business and repay debt.

Our Operating Assets and Contractual Arrangements

General

The following table sets forth information about our continuing operations after giving effect to the elimination of all intercompany activity. Facility production volume differs from sales volume due to changes in inventories and the sale of purchased blendstocks such as ethanol and specialty blendstocks, as well as the resale of crude oil.


	Year Ended December 31,
	2025	2024	% Change		2024	2023	% Change

	(In bpd)		(In bpd)
Total sales volume ⁽¹⁾	90,468	88,007	2.8	%	88,007	79,805	10.3	%
Facility production:
Specialty Products and Solutions:
Lubricating oils	12,012	11,927	0.7	%	11,927	10,358	15.1	%
Solvents	7,675	7,494	2.4	%	7,494	7,208	4.0	%
Waxes	1,405	1,415	(0.7)	%	1,415	1,326	6.7	%
Fuels, asphalt and other by-products	39,537	36,390	8.6	%	36,390	37,353	(2.6)	%
Total Specialty Products and Solutions	60,629	57,226	5.9	%	57,226	56,245	1.7	%
Montana/Renewables:
Gasoline	3,480	3,556	(2.1)	%	3,556	3,898	(8.8)	%
Diesel	2,642	2,830	(6.6)	%	2,830	2,941	(3.8)	%
Jet fuel	525	472	11.2	%	472	449	5.1	%
Asphalt, heavy fuel oils and other	3,779	3,983	(5.1)	%	3,983	4,483	(11.2)	%
Renewable fuels	11,270	9,848	14.4	%	9,848	6,314	56.0	%
Total Montana/Renewables	21,696	20,689	4.9	%	20,689	18,085	14.4	%

Performance Brands	1,570	1,739	(9.7)	%	1,739	1,474	18.0	%

Total facility production	83,895	79,654	5.3	%	79,654	75,804	5.1	%

(1)	Total sales volume includes sales from the production at our facilities and certain third-party facilities pursuant to supply and/or processing agreements, sales of inventories and the resale of crude oil to third-party customers. Total sales volume includes the sale of purchased blendstocks.

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The following table sets forth information about our sales of principal products by segment (dollars in millions):


	Year Ended December 31,
	2025				2024				2023
			% of Sales				% of Sales				% of Sales
Specialty Products and Solutions:
Lubricating oils	$	752.0	18.2	%	$	788.6	18.8	%	$	763.8	18.3	%
Solvents		401.6	9.7	%		407.3	9.7	%		398.5	9.5	%
Waxes		152.4	3.7	%		156.3	3.7	%		163.9	3.9	%
Fuels, asphalt and other by-products		1,327.0	32.1	%		1,437.1	34.4	%		1,550.7	37.1	%
Total	$	2,633.0	63.7	%	$	2,789.3	66.6	%	$	2,876.9	68.8	%
Montana/Renewables:
Gasoline	$	128.1	3.1	%	$	140.8	3.4	%	$	167.2	4.0	%
Diesel		102.6	2.5	%		114.6	2.7	%		144.8	3.5	%
Jet fuel		19.6	0.5	%		18.2	0.4	%		20.5	0.5	%
Asphalt, heavy fuel oils and other		159.0	3.8	%		159.6	3.8	%		148.1	3.5	%
Renewable fuels		783.8	18.9	%		631.7	15.1	%		513.2	12.3	%
Total	$	1,193.1	28.8	%	$	1,064.9	25.4	%	$	993.8	23.8	%

Performance Brands	$	311.0	7.5	%	$	335.2	8.0	%	$	310.3	7.4	%

Consolidated sales	$	4,137.1	100.0	%	$	4,189.4	100.0	%	$	4,181.0	100.0	%

Read Note 18 — “Segments and Related Information” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” of this Annual Report for additional financial information about each of our segments and the geographic areas in which we conduct business.

Northwest Louisiana Integrated Specialty Complex

The assets in our Northwest Louisiana integrated specialty complex anchor our Specialty Products and Solutions business segment. The assets in the Northwest Louisiana integrated specialty complex, primarily consist of our Shreveport facility, Cotton Valley facility and Princeton facility, which in total, includes 27 processing units and 195 million gallons of storage capacity across 400 tanks and have a wide variety of specialized hydroprocessing, dewaxing, emulsifying and distillation capabilities that allow us to meet complex, bespoke customer needs at scale providing an advantaged cost.

Shreveport Facility

The Shreveport facility (“Shreveport”), located on a 240 acre site in Shreveport, Louisiana, currently has aggregate crude oil throughput capacity of 60,000 bpd and processes paraffinic crude oil and associated feedstocks into fuel products, paraffinic lubricating oils, waxes, asphalt and by-products.

The Shreveport facility consists of 17 major processing units including hydrotreating, catalytic reforming and dewaxing units and approximately 3.3 million barrels of storage capacity in 130 storage tanks and related loading and unloading facilities and utilities. Since our acquisition of the Shreveport facility in 2001, we have expanded the facility’s capabilities by adding additional processing and blending facilities, adding a second reactor to the high pressure hydrotreater, resuming production of gasoline, diesel and other fuel products and adding both 18,000 bpd of crude oil throughput capacity and the capability to run up to 25,000 bpd of sour crude oil.

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The following table sets forth historical information about production at our Shreveport facility:


		Shreveport Facility
		Year Ended December 31,
		2025		2024		2023

		(In bpd)
Crude oil throughput capacity		60,000		60,000		60,000
Total feedstock runs ^{(1) (2)}		42,066		39,895		38,248
Total facility production^{(2) (3)}		44,191		41,749		40,290

(1)	Total feedstock runs represent the barrels per day of crude oil and other feedstocks processed at our Shreveport facility. Total feedstock runs do not include certain interplant feedstocks supplied by our Cotton Valley and Princeton facilities.

(2)

Total facility production represents the barrels per day of specialty products and fuel products yielded from processing crude oil and other feedstocks. The difference between total facility production and total feedstock runs is primarily a result of the time lag between the input of feedstocks and production of finished products and volume loss.

(3)	Total facility production includes certain interplant feedstock supplied to our Cotton Valley and Princeton facilities and our Karns City facility.

The Shreveport facility has a flexible operational configuration and operating personnel that facilitates the development of opportunities to enhance profitability. Feedstock and product mix may fluctuate from one period to the next to capture market opportunities.

The Shreveport facility receives crude oil via tank truck, railcar and a common carrier pipeline system that is operated by a subsidiary of Plains All American Pipeline, L.P. (“Plains”) and is connected to Shreveport’s facilities. The Plains pipeline system delivers local supplies of crude oil and condensates from north Louisiana and east Texas. The Plains pipeline also connects to a Plains terminal in Longview, TX, which gives the refinery access to crude oil in west Texas and access to the Cushing, Oklahoma storage hub. Crude oil is also purchased from various suppliers, including local producers, who deliver crude oil to the Shreveport facility via tank truck.

The Shreveport facility also has direct pipeline access to the Enterprise Products Partners L.P. pipeline (“TEPPCO pipeline”), on which it can ship certain grades of gasoline, diesel and jet fuel. Further, the refinery has direct access to the Red River Terminal facility, which provides the facility with barge access, via the Red River, to major feedstock and petroleum products logistics networks on the Mississippi River and Gulf Coast inland waterway system. The Shreveport facility also ships its finished specialty products throughout the U.S. through both truck and railcar service.

Cotton Valley Facility

The Cotton Valley facility (“Cotton Valley”), located on a 77 acre site in Cotton Valley, Louisiana, currently has aggregate crude oil throughput capacity of 13,600 bpd, hydrotreating capacity of 6,500 bpd and processes crude oil into specialty solvents and residual fuel oil. The residual fuel oil is an important feedstock for the production of specialty products at our Shreveport facility. We believe the Cotton Valley facility produces the most complete, single-facility line of paraffinic solvents in the U.S.

The Cotton Valley facility consists of three major processing units that include a crude unit, a hydrotreater and a fractionation train, approximately 625,000 barrels of storage capacity in 74 storage tanks and related loading and unloading facilities and utilities. Since our acquisition of the Cotton Valley facility in 1995, we have expanded the facility’s capabilities by installing a hydrotreater that removes aromatics, increased the crude unit processing capability to 13,600 bpd and reconfigured the facility’s fractionation train to improve product quality, enhance flexibility and lower utility costs.

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The following table sets forth historical information about production at our Cotton Valley facility:


		Cotton Valley Facility
		Year Ended December 31,
		2025		2024		2023

		(In bpd)
Crude oil throughput capacity		13,600		13,600		13,600
Total feedstock runs ^{(1) (2)}		10,136		9,875		9,125
Total facility production ^{(2) (3)}		6,024		6,072		6,571

(1)	Total feedstock runs do not include certain interplant solvent feedstocks supplied by our Shreveport facility.

(2)

Total facility production represents the barrels per day of specialty products yielded from processing crude oil and other feedstocks. The difference between total facility production and total feedstock runs is primarily a result of the time lag between the input of feedstocks and the production of finished products, intermediates transferred to internal sites for further processing, and volume loss.

(3)	Total facility production includes certain interplant feedstocks supplied to our Shreveport facility.

The Cotton Valley facility has a flexible operational configuration and operating personnel that facilitates the development of opportunities to enhance profitability. Feedstock and product mix may fluctuate from one period to the next to capture market opportunities, which allows us to respond to market changes and customer demands by modifying the refinery’s product mix. The reconfigured fractionation train also allows the facility to satisfy demand fluctuations efficiently without large finished product inventory requirements.

The Cotton Valley facility receives crude oil via tank truck. The Cotton Valley facility’s feedstock is primarily low sulfur and paraffinic crude oil originating from north Louisiana and is purchased from various marketers and gatherers. In addition, the Cotton Valley facility receives interplant feedstocks for solvent production from the Shreveport facility. The Cotton Valley facility ships finished products by both truck and railcar service. No transportation fuels are produced at the Cotton Valley site.

Princeton Facility

The Princeton facility (“Princeton”), located on a 208 acre site in Princeton, Louisiana, currently has aggregate crude oil throughput capacity of 10,000 bpd and processes naphthenic crude oil into lubricating oils and asphalt. In addition, feedstock is made for the Shreveport facility for further processing into ultra-low sulfur diesel. The asphalt produced at Princeton may be further processed or blended for coating and roofing product applications at the Princeton facility or transported to the Shreveport facility for further processing into bright stock.

The Princeton facility consists of seven major processing units, approximately 650,000 barrels of storage capacity in 200 storage tanks and related loading and unloading facilities and utilities. Since our acquisition of the Princeton facility in 1990, we have debottlenecked the crude unit to increase production capacity to 10,000 bpd, increased the hydrotreater’s capacity to 7,000 bpd and upgraded the facility’s fractionation unit, which has enabled us to produce higher value specialty products.

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The following table sets forth historical information about production at our Princeton facility:


		Princeton Facility
		Year Ended December 31,
		2025		2024		2023

		(In bpd)
Crude oil throughput capacity		10,000		10,000		10,000
Total feedstock runs ⁽¹⁾		7,485		7,512		7,724
Total facility production ^{(1) (2)}		5,428		5,107		5,631

(1)

(2)	Total facility production includes certain interplant feedstocks supplied to our Shreveport facility.

The Princeton facility has a hydrotreater and significant fractionation capability enabling the refining of high quality naphthenic lubricating oils at numerous distillation ranges. The Princeton facility’s processing capabilities consist of atmospheric and vacuum distillation, hydrotreating, asphalt oxidation processing and clay/acid treating. In addition, we have the necessary tankage and technology to process our asphalt into higher value product applications such as coatings, road paving and specialty applications.

The Princeton facility receives crude oil via tank truck, railcar and the Plains pipeline system. Its crude oil supply primarily originates from east Texas, south Texas and north Louisiana, purchased directly from third-party suppliers under month-to-month evergreen supply contracts and on the spot market. The Princeton facility ships its finished products throughout the U.S. via truck and railcar service. No transportation fuels are produced at the Princeton facility site.

Montana Specialty Asphalt Facility (CMR)

The Montana specialty asphalt facility, located on a 65 acre site in Great Falls, Montana, currently has aggregate crude oil throughput capacity of 15,000 bpd and processes light and heavy crude oil from Canada into fuel and asphalt products. We also lease, with a purchase option, 870 acres of land nearby for strategic expansion. In 2022, we converted a significant portion of the Montana specialty asphalt facility into a renewable fuels production facility (see below). Upon completion of the conversion project, we continue to own and operate the conventional Montana specialty asphalt facility with a reconfigured processing capacity of 15,000 bpd of Canadian crude. The facility is focused on the production of high-quality specialty asphalt, as well as satisfying local demand for conventional fuels.

The Montana specialty asphalt facility consists of 15 major processing units including hydrotreating, catalytic reforming, hydrocracking, fluid catalytic cracking and alkylation units, approximately 500,000 barrels of tank shell storage capacity in 75 tanks and related loading and unloading facilities and utilities.

The following table sets forth historical information about production at the Montana specialty asphalt facility:


		Montana Specialty Asphalt Facility
		Year Ended December 31,
		2025		2024		2023

		(In bpd)
Crude oil throughput capacity		15,000		15,000		15,000
Total feedstock runs ^{(1) (2)}		10,800		11,356		11,982
Total facility production⁽²⁾		10,426		10,841		11,772

(1)	Total feedstock runs represent the barrels per day of crude oil processed at our Montana specialty asphalt facility.

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(2)

Currently, the Montana specialty asphalt facility produces liquified petroleum gas, naphtha, gasoline, diesel, jet fuel and asphalt, which are shipped by railcar and truck service. Finished fuel and asphalt sales are primarily made through spot agreements and short-term contracts.

The Montana specialty asphalt facility purchases crude oil from various suppliers and receives crude oil through the Interprovincial Bow River South and Rangeland pipeline systems, providing reliable access to high quality conventional crude oil from western Canada.

The specialty asphalt facility capitalizes on local access to cost-advantaged Canadian conventional crude oil, while producing additional fuels and refined products for delivery into the regional market while meeting EPA requirements for gasoline and diesel product sulfur limits and reducing air emissions. The renewable fuels facility is described below.

Montana Renewable Fuels Facility (“Montana Renewables”)

In 2022, Montana Renewables LLC, an unrestricted subsidiary of Calumet, completed the conversion of a significant portion of our Montana specialty asphalt facility into a renewable fuels production facility (the “Montana Renewables Facility”). The Montana Renewables Facility has a permitted throughput capacity of 15,000 bpd to pretreat and convert a wide variety of organic waste and seed oils into lower emissions, sustainable alternatives to fossil fuels, including renewable naphtha, renewable kerosene/sustainable aviation fuel, and renewable diesel.

As part of the conversion project, we also constructed and commissioned an innovative renewable hydrogen unit, which further lowered carbon intensity and increased the throughput of the Montana Renewables facility. Further, a new state of the art feedstock pre-treater, which combined with proximity to advantaged feedstocks and low-carbon product markets provides lasting competitive advantage to Montana Renewables.

Missouri Facility

The Missouri facility (“Missouri”), located on a 22 acre site in Louisiana, Missouri, develops and produces polyol ester synthetic lubricants for use in refrigeration compressors, commercial aviation and polyol ester base stocks. In 2015, we completed a project to more than double the production capacity of the facility from 35 million pounds to 75 million pounds per year. The facility has approximately 35,000 barrels of storage capacity in 64 tanks and related loading and unloading facilities and utilities. The facility receives its fatty acids and alcohol feedstocks and additives by truck and railcar under supply agreements or spot agreements with various suppliers.

The Missouri facility utilizes the latest batch esterification processes designed to ensure blending accuracy while maintaining production flexibility to meet customer needs.

Calumet Packaging Facility

The Calumet Packaging facility (“Calumet Packaging”), located on a 10 acre site in Shreveport, Louisiana, develops, blends and packages high performance synthetic lubricants, fuels and solvent products for use in industrial, commercial and automotive applications. The Calumet Packaging facility’s processing capability includes state-of-the-art blending and packaging equipment. The facility has approximately 75,000 barrels of storage capacity and related loading and unloading facilities. The facility receives its base oil feedstocks and additives by truck and rail under supply agreements or spot agreements with various suppliers.

Royal Purple Facility

The Royal Purple facility (“Royal Purple”), located on a 20 acre site in Porter, Texas, develops, blends and packages high performance synthetic lubricants and fluid additive products for use in industrial, commercial and automotive

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applications. The Royal Purple facility’s processing capability includes 10 in-house packaging and production lines. Outsourced packaging services for specific products are also fulfilled. The facility has approximately 30,500 barrels of storage capacity in 91 tanks and related loading and unloading facilities. The facility receives its base oil feedstocks and additives by truck under supply agreements or spot agreements with various suppliers.

On February 28, 2025, the Company announced that it entered into a definitive agreement with a wholly owned subsidiary of Lubrication Engineers, Inc., a portfolio company of Aurora Capital Partners, to sell assets related to the industrial portion of its Royal Purple® business, for $110.0 million, subject to certain customary adjustments. The Company retained the consumer portion of the Royal Purple® business. At the closing of the transaction on March 31, 2025, the Company received cash proceeds of $96.9 million, with a remaining deferred payment of $1.5 million to be received in 2026, net of working capital adjustments and transaction related expenses. During 2025, the Company recorded a $55.8 million gain on the sale of business in the consolidated statements of operations. The total consideration is final, and no additional post-closing adjustments or continuing obligations remain. The Company has recognized the gain on sale based on the finalized consideration, and no further changes to the recorded gain or loss are expected.

Karns City and Dickinson Facilities and Other Processing Agreements

The Karns City facility (“Karns City”), located on a 225 acre site in Karns City, Pennsylvania, has aggregate base oil throughput capacity of 3,000 bpd and produces white mineral oils, solvents, petrolatums, gelled hydrocarbons, cable fillers and natural petroleum sulfonates. The Karns City facility’s processing capability includes hydrotreating, fractionation, acid treating, filtering, blending and packaging. In addition, the facility has approximately 817,000 barrels of storage capacity in 250 tanks and related loading and unloading facilities and utilities.

The Dickinson facility (“Dickinson”), located on a 28 acre site in Dickinson, Texas, has aggregate base oil throughput capacity of 1,300 bpd and produces white mineral oils, compressor lubricants and natural petroleum sulfonates. The Dickinson facility’s processing capability includes acid treating, filtering and blending. The facility has approximately 183,000 barrels of storage capacity in 186 tanks and related loading and unloading facilities and utilities.

These facilities each receive their base oil feedstocks by railcar and truck under supply agreements or spot purchases with various suppliers, the most significant of which is a supply agreement with Phillips 66. Read “— Our Crude Oil and Feedstock Supply” below for further discussion of the long-term supply agreement with Phillips 66.

The following table sets forth the combined historical information about production at our Karns City, Dickinson and certain other facilities:


		Combined Karns City, Dickinson and Other Facilities
		Year Ended December 31,
		2025		2024		2023

		(in bpd)
Feedstock throughput capacity ⁽¹⁾		11,300		11,300		11,300
Total feedstock runs^{(2) (3)}		4,479		4,011		3,396
Total production⁽³⁾		4,695		3,999		3,419

(1)	Includes Karns City, Dickinson and certain other facilities.

(2)	Includes feedstock runs at our Karns City and Dickinson facilities as well as throughput at certain third-party facilities pursuant to supply and/or processing agreements and includes certain interplant feedstocks supplied from our Shreveport facility.

(3)

Total production represents the barrels per day of specialty products yielded from processing feedstocks at our Karns City and Dickinson facilities and certain third-party facilities pursuant to supply and/or processing agreements. The difference between total production and total feedstock runs is primarily a result of the time lag between the input of feedstocks and the production of finished products.

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Other Logistics Assets

Terminals are complementary to our refineries and play a key role in moving our products to end-user markets by providing services including distribution and blending to achieve specified products and storage and inventory management. In addition to the Burnham terminal, we own and lease additional facilities, primarily related to distribution of finished products, throughout the U.S.

Burnham Terminal: We own and operate a terminal located on an 11 acre site, in Burnham, Illinois. The Burnham terminal receives specialty products from certain of our refineries primarily by railcar and distributes them by truck and railcar to our customers in the Upper Midwest and East Coast regions of the U.S. and in Canada. The terminal includes a tank farm with 90 tanks having aggregate storage capacity of approximately 150,000 barrels, supplying lube base oils, food grade white oils and aliphatic solvents, as well as viscosity index additives and tackifiers.

We use approximately 2,300 railcars leased from various lessors. This fleet of railcars enables us to receive and ship crude oil and distribute various specialty products and fuel products throughout the U.S. and Canada to and from each of our facilities. In addition, we use approximately 350 leased railcars to source renewable feedstocks and distribute renewable fuels products into the western half of North America.

Our Crude Oil and Feedstock Supply

We purchase crude oil and other feedstocks from major oil companies as well as from various crude oil gatherers and marketers in Texas, north Louisiana and Canada. Crude oil supplies at our facilities are as follows:


Facility	Crude Oil / Feedstock Slate	Mode of Transportation
Shreveport	West Texas Intermediate (“WTI”), local crude oils from East Texas, North Louisiana, Arkansas and Light Louisiana Sweet (“LLS”)	Tank truck, railcar and Plains Pipeline
Cotton Valley	Local paraffinic crude oil	Tank truck
Montana Specialty Asphalt Facility	Canadian Heavy (e.g. Bow River) and Canadian Light Sour	Front Range Pipeline
Montana Renewables Facility	Organic waste and seed oil materials	Railcar
Princeton	Local and imported naphthenic crude oil	Tank truck, railcar and Plains Pipeline

In 2025, BP Oil Supply Co. (“BP”) supplied us with approximately 39.3% of our total crude oil supply under term contracts and month-to-month evergreen crude oil supply contracts. In 2025, Macquarie Commodities Trading US, LLC. (“Macquarie”) supplied us with approximately 20.0% of our total crude oil supply under a crude oil supply agreement. Each of our facilities is dependent on one or more key suppliers and the loss of any of these suppliers would adversely affect our financial results to the extent we were unable to find another supplier of this substantial amount of crude oil.

We have short-term and long-term contracts with our crude oil suppliers. For example, a majority of our crude oil supply contracts with Plains are currently month-to-month and terminable upon 90 days’ notice. Additionally, our crude oil supply agreement with BP was amended and restated in December 2016, and automatically renews for successive one-year terms each March unless terminated by either party upon 90 days’ notice (“BP Purchase Agreement”). This agreement has not been terminated by either party. We also purchase foreign crude oil when its spot market price is attractive relative to the price of crude oil from domestic sources.

MRL, an unrestricted subsidiary of the Company, has entered into various term supply agreements for renewable feedstocks that are key to the operations of the Montana Renewables facility.

We have various long-term feedstock supply agreements with Phillips 66, with some agreements operating under the option to continue on a month-to-month basis thereafter, for feedstocks that are key to the operations of our Karns City and Dickinson facilities. In addition, certain products of our refineries can be used as feedstocks by these facilities.

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We believe that adequate supplies of crude oil and feedstocks will continue to be available to us.

Our cost to acquire crude oil and feedstocks and the prices for which we ultimately can sell refined products depend on a number of factors beyond our control, including regional and global supply of and demand for crude oil, other feedstocks and specialty and fuel products. These, in turn, are dependent upon, among other things, the availability of imports, overall economic conditions, production levels of domestic and foreign suppliers, U.S. relationships with foreign governments, political affairs and the extent of governmental regulation. We have historically been able to pass on the costs associated with increased crude oil and feedstock prices to our specialty products customers, although the increase in selling prices for specialty products typically lags the rising cost of crude oil. From time to time, we use a hedging program to manage a portion of our commodity price risk.

Our Products, Markets and Customers

Products

We produce a full line of specialty products, including lubricating oils, solvents, waxes, food grade white oils, pharmaceutical grade petrolatums, and other products, as well as a variety of fuel and fuel related products, including asphalt and heavy fuel oils. We also blend, package and market high performance specialty products through our Royal Purple, Bel-Ray, and TruFuel brands. At our Montana Renewables facility, we produce a variety of renewable fuels products, including renewable diesel, sustainable aviation fuel, and renewable naphtha that are distributed into renewable markets in the western half of North America. Our customers purchase specialty products primarily as raw material components for consumer-facing and industrial products. Our customers also purchase renewable fuels, which are consumed to reduce lifecycle carbon emissions.

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The following table depicts a representative sample of the diversity of end-use applications for the products we produce:

Representative Sample of End-Use Applications by Product ⁽¹⁾

Lubricating Oils	Solvents	Waxes	Packaged and Synthetic Specialty Products	Fuels & Fuel Related Products	Renewable Products
18%	10%	4%	7%	42%	19%
● Hydraulic oils ● Passenger car motor oils ● Railroad engine oils ● Cutting oils ● Compressor oils ● Metalworking fluids ● Transformer oils ● Rubber process oils ● Industrial lubricants ● Gear oils ● Grease ● Automatic transmission fluid ● Animal feed dedusting ● Baby oils ● Bakery pan oils ● Catalyst carriers ● Gelatin capsule lubricants ● Sunscreen	● Waterless hand cleaners ● Alkyd resin diluents ● Automotive products ● Calibration fluids ● Charcoal lighter fluids ● Chemical processing ● Drilling fluids ● Printing inks ● Water treatment ● Paint and coatings ● Stains	● Paraffin waxes ● FDA compliant products ● Candles ● Adhesives ● Crayons ● Floor care ● PVC ● Paint strippers ● Skin & hair care ● Timber treatment ● Waterproofing ● Pharmaceuticals ● Cosmetics	● Refrigeration compressor oils ● Positive displacement and roto-dynamic compressor oils ● Commercial and military jet engine oil ● Lubricating greases ● Gear oils ● Aviation hydraulic oils ● High performance small engine fuels ● Two cycle and four stroke engine oils ● High performance automotive engine oils ● High performance industrial lubricants ● High temperature chain lubricants ● Food contact grade lubricants ● Charcoal lighter fluids and other solvents ● Engine treatment additives	● Gasoline ● Diesel ● Jet fuel ● Marine fuel ● Ethanol free fuels ● Fluid catalytic cracking feedstock ● Asphalt vacuum residuals ● Mixed butanes ● Roofing flux ● Paving asphalt ● Heavy fuel oils	● Renewable naphtha ● Renewable kerosene/sustainable aviation fuel ● Renewable diesel

(1)	Based on the percentage of total sales for the year ended December 31, 2025. Except for the listed fuel products, renewable products and certain packaged and synthetic specialty products, we do not produce any of these end-use products.

Marketing

Our salespeople regularly visit customers and work in conjunction with our marketing department, the laboratories at our production facilities and our technical services department, to focus on providing additional value to our customers, such as formulation assistance, regulatory insight, and creating specialized blends and packaging that work optimally for our customers.

Markets

Specialty Products. The specialty products market represents a small portion of the overall petroleum refining industry in the U.S. Of the approximately 130 refineries currently in operation in the U.S., only a small number of the refineries are considered specialty products producers and only a few compete with us in terms of the number of products produced.

Our specialty products are utilized in applications across a broad range of industries, including:

●

industrial goods such as finished lubricants, batteries, water treatment chemistry, mining lubricants, oilfield drilling, electrical and transformer oils, adhesives, refrigeration compressor oils, aviation fluids, and agriculture applications; and

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●

consumer goods such as cosmetics, petroleum jelly, lotions, pharmaceuticals, food, candles, paint and coatings, charcoal lighter fluids, and car care products.

We have the capability to ship our specialty products worldwide. In the U.S., we ship our specialty products via railcars, trucks and barges. We use our fleet of leased railcars to ship our specialty products and a majority of our specialty products sales are shipped in trucks owned and operated by several different third-party carriers. For international shipments, which accounted for less than 10% of our consolidated sales in 2025, we ship via railcars and trucks to several ports where the product is loaded onto vessels for shipment to customers abroad.

Fuel Products. The fuel products market represents a large portion of the overall petroleum refining industry in the U.S. Of the approximately 130 refineries currently in operation in the U.S., a large number of the refineries are fuel products producers; however, only a few compete with us in our local markets.

Renewable Fuel Products. The renewable fuel products market represents a small portion of the overall transportation fuels industry in the U.S. MRL is a leading independent producer of renewable transportation fuels in North America and one of the largest SAF producers in the western hemisphere. The renewable fuels market is in the rapid-growth phase of its life cycle, and we believe SAF demand will continue to grow at a rapid rate. We believe we are well positioned to benefit from these trends.

Gulf Coast Market (PADD 3)

Fuel products produced at our Shreveport facility can be sold locally or to the Midwest region of the U.S. through the TEPPCO pipeline. Local sales are made from the TEPPCO terminal in Bossier City, Louisiana, located approximately 15 miles from the Shreveport facility, as well as from our own Shreveport facility terminal.

Gasoline, diesel and jet fuel from the Shreveport facility are sold primarily into the Louisiana, Texas and Arkansas markets, and any excess volumes are sold to marketers further up the TEPPCO pipeline. Should the appropriate market conditions arise, we have the capability to redirect and sell additional volumes into the Louisiana, Texas and Arkansas markets rather than transport them to the Midwest region via the TEPPCO pipeline.

The Shreveport facility has the capacity to produce approximately 9,000 bpd of commercial jet fuel that can be marketed to the U.S. Department of Defense, sold as Jet-A locally or sold via the TEPPCO pipeline, or transferred to the Cotton Valley facility to be processed further as a feedstock to produce solvents.

Additionally, we produce a number of fuel-related products including fluid catalytic cracking (“FCC”) feedstock, vacuum residuals and mixed butanes. FCC feedstock is sold to other refiners as a feedstock for their FCC units to make fuel products. Vacuum residuals are blended or processed further to make asphalt products. Volumes of vacuum residuals which we cannot process are sold locally into the fuel oil market or sold via railcar to other refiners. Mixed butanes are primarily available in the summer months and are primarily sold to local marketers. If the mixed butanes are not sold, they are blended into our gasoline production.

Northwest Market (PADD 4)

Fuel and asphalt products produced at our Montana specialty asphalt facility can be sold locally and in Missouri, Oklahoma, Texas, Arizona, North Dakota, South Dakota, Idaho, Oregon, Utah, Wyoming, Washington, Nevada, California and Canada. Seasonally, fuel products from the Montana specialty asphalt facility are transported to terminals in Washington and Utah.

Renewable diesel, sustainable aviation fuel, and renewable naphtha produced at our Montana Renewables facility are distributed into renewable markets in the western half of North America.

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Customers

Specialty Products. We have a diverse customer base for our specialty products. In fiscal year 2025, we sold our specialty products to approximately 2,200 customers. Many of our customers are long-term customers who use our products in specialty applications, after an approval process ranging from six months to two years.

Fuel Products. We have a diverse customer base for our fuel products. In fiscal year 2025, we sold our fuel products to approximately 200 customers. Our diverse customer base includes wholesale distributors and retail chains. We are able to sell the majority of the fuel products we produce at the Shreveport facility to the local markets of Louisiana, Texas and Arkansas. We also have the ability to ship additional fuel products from the Shreveport facility to the Midwest region through the TEPPCO pipeline. The majority of our fuel products produced at our Montana specialty asphalt facility are sold to local markets in Montana and Idaho as well as in Canada.

Renewable Fuels Products. We sell our renewable fuels products to a relatively small number of investment grade counterparties under multiyear offtake agreements for onward distribution into renewable markets in the western half of North America. The robust demand during the placement process for the renewable fuels produced at our Montana Renewables facility allows us to select an established, integrated customer base for our renewable products.

During the years ended December 31, 2025, 2024, and 2023, we had no customer that represented 10% or greater of consolidated sales.

Competition

Competition in our markets is from a combination of large, integrated petroleum companies and independent refiners. Many of our competitors are substantially larger than us and are engaged on a national or international basis in many segments of the petroleum products business, including exploration and production, refining, transportation and marketing. These competitors may have greater flexibility in responding to or absorbing market changes occurring in one or more of these business segments. We distinguish our competitors according to the products that they produce. Set forth below is a description of our significant competitors according to product category.

Naphthenic Lubricating Oils. Our primary competitors in producing naphthenic lubricating oils include Ergon Refining, Inc., Cross Oil Refining and Marketing, Inc. and San Joaquin Refining Co., Inc.

Paraffinic Lubricating Oils. Our primary competitors in producing paraffinic lubricating oils include Exxon Mobil Corporation, Motiva Enterprises, LLC, Phillips 66, HF Sinclair Corporation and Chevron Corporation.

Paraffin Waxes. Our primary competitors in producing paraffin waxes include Exxon Mobil Corporation, HF Sinclair Corporation, The International Group Inc. and Ergon, Inc.

Solvents. Our primary competitors in producing solvents include CITGO Petroleum Corporation, ExxonMobil Chemical Company and Total S.A.

Polyol ester Based Specialty Products. Our primary competitors in producing polyol ester-based specialty products include LANXESS, ExxonMobil Corporation, BASF Corporation, Croda International plc, Nyco Products Corporation and Zschimmer & Schwartz, Inc.

Packaged and Synthetic Specialty Products. Our primary competitors in retail and commercial packaged and synthetic specialty products include Exxon Mobil Corporation (Mobil 1), Valvoline, Inc. and other independent lubricant manufacturers. Our primary competitors in industrial packaged and synthetic specialty products include Exxon Mobil Corporation, Royal Dutch Shell plc, Fuchs and other independent lubricant manufacturers.

Fuel Products and By-Products. Our primary competitors in producing fuel products in the local markets in which we operate include Delek US Holdings, Exxon Mobil Corporation, Phillips 66 and Cenex.

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Renewable Fuel Products. Our primary competitors in producing renewable fuel products in the U.S. West Coast markets are Marathon Petroleum Company, Phillips 66 and Chevron Corporation. A significant portion of our renewable products are placed in other markets which lack indigenous renewables production.

Our ability to compete effectively depends on our responsiveness to customer needs and our ability to maintain competitive prices and product and service offerings. We believe that our flexibility and customer responsiveness differentiates us from many of our larger competitors. However, it is possible that new or existing competitors could enter the markets in which we operate, which could negatively affect our financial performance.

Governmental Regulation

Our business is subject to comprehensive and complex federal, state, tribal, and local laws and regulations governing the protection of the environment and worker health and safety, as well as the discharge of materials and emissions into the environment. Various governmental agencies promulgate and enforce regulatory schemes to implement and enforce these laws, compliance with which can be costly. These laws and regulations frequently change in response to economic or political conditions, or other developments, and our regulatory burden may increase in the future. Such laws and regulations have the potential to increase our cost of conducting business. Further, from time to time, we are a party to certain claims and litigation incidental to our business, including claims made by various taxation and regulatory authorities, such as the Internal Revenue Service (“IRS”), the Environmental Protection Agency (“EPA”) and the U.S. Occupational Safety and Health Administration (“OSHA”), as well as various state environmental regulatory bodies and state and local departments of revenue, as the result of audits or reviews of our business.

Environmental and Occupational Health and Safety Matters

Environmental

We conduct crude oil and specialty refining, blending and terminal operations, certain activities of which are subject to stringent federal, regional, state and local laws and regulations governing worker health and safety, the discharge of materials into the environment, and environmental protection. These laws and regulations impose legal standards and obligations that are applicable to our operations, such as requiring the acquisition of permits to conduct regulated activities, restricting the manner in which we may release materials into the environment, requiring mitigation of pollutant discharges from current operations that may include incurring capital expenditures to limit or prevent unauthorized releases from our equipment and facilities, requiring remedial activities to mitigate pollution from former operations, imposing substantial liabilities for pollution resulting from our operations, and requiring the application of specific health and safety criteria addressing worker protection. Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil and criminal penalties; the imposition of investigatory, remedial or corrective action obligations or the incurrence of capital expenditures; the occurrence of restrictions, delays or cancellations in the permitting, development or expansion of projects; and the issuance of injunctive relief limiting or prohibiting our activities in a particular area.

Moreover, certain of these laws impose joint and several liability and strict liability for costs required to remediate and restore sites where petroleum hydrocarbons, wastes or other materials have been disposed of or released and areas where any such contamination has come to be located. In addition, new environmental and worker safety laws and regulations, amendment of existing laws and regulations, reinterpretation of legal requirements, increased governmental enforcement or other developments could significantly increase our operational or compliance expenditures, including as discussed below in more detail.

Remediation of subsurface contamination continues at certain of our refinery sites and is being overseen by the appropriate governmental agencies. Based on current investigative and remedial activities, we believe that the cost to control or remediate the soil and groundwater contamination at these refineries will not have a material adverse effect on our financial condition. However, such costs are often unpredictable and, therefore, there can be no assurance that the future costs of these remedial projects will not become material.

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Great Falls Refinery / Montana Specialty Asphalt Facility

In connection with the acquisition of the Great Falls refinery from Connacher Oil and Gas Limited (“Connacher”), we became a party to an existing 2002 Refinery Initiative Consent Decree (the “Great Falls Consent Decree”) with the EPA and the Montana Department of Environmental Quality (the “MDEQ”). The material obligations imposed by the Great Falls Consent Decree have been completed. On September 27, 2012, Montana Refining Company, Inc., received a final Corrective Action Order on Consent, replacing the refinery’s previously held hazardous waste permit. This Corrective Action Order on Consent governs the investigation and remediation of contamination at the Great Falls refinery.

We believe the majority of the impacts related to such historical contamination at the Great Falls refinery are covered by a contractual indemnity provided by a subsidiary of HF Sinclair Corporation (the “Seller”), the owner and operator of the Great Falls refinery prior to its acquisition by Connacher, under an asset purchase agreement between the Seller and Connacher, pursuant to which Connacher acquired the Great Falls refinery.

Under this asset purchase agreement, the Seller agreed to indemnify Connacher and Montana Refining Company, Inc., subject to timely notification, certain conditions and certain monetary baskets and caps, for environmental conditions arising under the Seller’s ownership and operation of the Great Falls refinery and existing as of the date of sale to Connacher. During 2014, HF Sinclair Corporation (“Holly”) provided us a notice challenging our position that the Seller is obligated to indemnify our remediation expenses for environmental conditions to the extent arising under Seller’s ownership and operation of the refinery and existing as of the date of sale to Connacher. On September 22, 2015, we initiated a lawsuit against Holly and the Sellers. The court ordered that all of the claims be addressed in arbitration. The arbitration panel confirmed that the Sellers of the Great Falls refinery retained the liability for all pre-closing contamination with respect to third-party claims indefinitely and with respect to first party claims for which the Sellers received notice within five years after the sale of the refinery, which claims are subject to the requirements otherwise set forth in the asset purchase agreement. Among other things, the panel denied the Company’s demands for reimbursement for costs already incurred by the Company prior to the arbitration but left open the Company’s ability to make future claims. The Company expects that it may incur costs to remediate other environmental conditions at the Great Falls refinery. The Company currently believes that these other costs it may incur will not be material to its financial position or results of operations.

Air Emissions

Our operations are subject to the federal Clean Air Act, as amended (“CAA”), and comparable state and local laws. Amendments made to the CAA in 1990 require most industrial operations in the U.S. to incur capital expenditures to meet the air emission control standards that are developed and implemented by the EPA and state environmental agencies. Under the CAA, facilities that emit regulated air pollutants are subject to stringent regulations, including requirements to install various levels of control technology on sources of pollutants. In addition, in recent years, the petroleum refining sector has become subject to stringent federal regulations that impose maximum achievable control technology (“MACT”) on refinery equipment emitting certain listed hazardous air pollutants. Some of our facilities have been included within the categories of sources regulated by MACT rules. Our refining and terminal operations that emit regulated air pollutants are also subject to air emissions permitting requirements that incorporate stringent control technology requirements for which we may incur significant capital expenditures. Any renewal of those air emissions permits or a need to modify existing or obtain new air emissions permits has the potential to delay the development of our projects. We can provide no assurance that future compliance with existing or any new laws, regulations or permit requirements will not have a material adverse effect on our business, financial position or results of operations. For example, in 2015, the EPA issued a final rule under the CAA making the National Ambient Air Quality Standard (“NAAQS”) for ground-level ozone more stringent. Since that time, the EPA has issued area designations with respect to ground-level ozone and final requirements that apply to state, local and tribal air agencies for implementing the 2015 NAAQS for ground-level ozone. States are expected to implement more stringent requirements as a result of this new final rule, which could apply to our operations. EPA retained the 2015 standards for ground-level ozone after a review completed in 2020. In 2021, EPA announced that it would reconsider this standard, and in August 2023, EPA announced it would begin an entirely new review of the NAAQS for ground-level ozone, and in December 2024, EPA published Volumes 1 and 2 of its Integrated Review Plan. Also, in 2015, the EPA published a final rule that amended three refinery standards already in effect, imposing additional or, in some cases, new emission control requirements on subject refineries. The final rule requires, among other things, the monitoring of air concentrations of benzene around the refinery fence line perimeter and submittal of the fence line monitoring data

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to the EPA on a quarterly basis; upgraded emissions controls for storage tanks, including controls for smaller capacity storage vessels and storage vessels storing materials with lower vapor pressures than previously regulated; enhanced performance requirements for flares including the use of a minimum of three pollution prevention measures, continuous monitoring of flares and pressure release devices and analysis and remedy of flare release events; and compliance with emissions standards for delayed coking units. These final rules and any other future air emissions rulemakings could impact us by requiring installation of new emission controls on some of our equipment, resulting in longer permitting timelines, and significantly increasing our capital expenditures and operating costs, which could adversely impact our business.

The CAA authorizes the EPA to periodically require modifications in the formulation of the refined transportation fuel products we manufacture in order to limit the emissions associated with the fuel product’s final use. For example, in February 2000, the EPA published regulations limiting the sulfur content allowed in gasoline. These regulations, referred to as “Tier 2 Standards,” required the phase-in of gasoline sulfur standards beginning in 2004, with special provisions for small refiners and for refiners serving those western U.S. states exhibiting lesser air quality problems. Similarly, the EPA published regulations that limit the sulfur content of highway diesel beginning in 2006 from its former level of 500 parts per million (“ppm”) to 15 ppm (the “ultra-low sulfur standard”). Our Shreveport and Great Falls facilities have implemented the sulfur standard with respect to produced gasoline and produced diesel meeting the ultra-low sulfur standard.

In 2014, the EPA published more stringent sulfur standards, referred to as “Tier 3 Standards,” including requiring that motor gasoline will not contain more than 10 ppm of sulfur on an annual average basis. Our Shreveport and Great Falls facilities are fully compliant with the 10 ppm sulfur standard with respect to produced gasoline. In addition, we are required to meet the Mobile Source Air Toxics (“MSAT”) II Standards adopted by the EPA to reduce the benzene content of motor gasoline produced at our facilities and have completed capital projects at our Shreveport and Great Falls facilities to comply with those fuel quality requirements.

The EPA has issued RFS mandates, requiring refiners such as us to blend renewable fuels into the petroleum fuels they produce and sell in the U.S. We, and other refiners subject to RFS, may meet the RFS requirements by blending the necessary volumes of renewable transportation fuels produced by us or purchased from third parties. To the extent that refiners are unable to blend renewable fuels into the products they produce in the quantities required to satisfy their obligations under the RFS program, those refiners may purchase renewable credits, referred to as RINs, to maintain compliance. To the extent that we exceed the minimum volumetric requirements for blending of renewable transportation fuels, we generate our own RINs for which we have the option of retaining the RINs for current or future RFS compliance or selling those RINs on the open market. We are currently unable to blend sufficient quantities of ethanol and biodiesel to meet our requirements and, therefore, may have to purchase an increasing number of RINs. It is not possible at this time to predict with certainty what those volumes or costs may be. Existing laws and regulations could change, including the minimum volumes of renewable fuels that must be blended with refined petroleum fuels. For more information on the RFS program, our participation in the program and risks associated with the program, see the following risk factor under Part I, Item 1A of this Form 10-K: “The availability and cost of renewable identification numbers and results of litigation related to our SRE petitions could have a material adverse effect on our results of operations and financial condition and our ability to make payments on our debt obligations.”

Further, it is not possible to predict how changes to the regulatory landscape will develop or impact costs. The current administration has signaled its intent to roll back regulations addressing emissions and other environmental standards. For example, in November 2025, the Trump administration asked the U.S. Court of Appeals to strike down EPA limits on fine particulate matter (PM2.5), also known as soot, that the EPA had previously strengthened in 2024. And, as discussed in the following paragraphs, in February of 2026, the EPA announced it was eliminating both the Obama-era 2009 Greenhouse Gas (GHG) Endangerment Finding and all subsequent federal GHG emission standards for all vehicles and engines of model years 2012 to 2027 and beyond. These actions could encourage state governments to attempt to impose stricter regulations in order to account for federal deregulation, but any prediction regarding how such actions would impact the larger regulatory landscape or operating/compliance costs is impossible.

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Climate Change

The threat of climate change continues to attract considerable public, governmental and scientific attention, both in the U.S. and internationally. As a result, numerous proposals have been made and are likely to continue to be made by international, national, regional, state, and local governments to monitor and limit emissions of greenhouse gases (“GHG”) and to control such future emissions. Consequently, it is possible that our operations as well as the operations of our customers may become subject to increased regulatory, political, physical, litigation and financial risks associated with the processing of fossil fuels and/or emissions of GHGs. The adoption of legislation or regulations or other regulatory initiatives by international, national, regional, state, and local governments that impose more stringent standards for GHG emissions could require us to incur increased compliance costs or affect the price or availability of certain of our feedstocks or products.

At the federal level, the Inflation Reduction Act (“IRA”) was signed into law in August 2022, which contained tax inducements and other provisions that incentivize investment, development, and deployment of alternative energy sources and technology, which could increase operating costs within the oil and gas industry and accelerate the transition away from fossil fuels. The current administration has diverged from prior administration’s positions, and the passage of the One Big Beautiful Bill Act rescinded many IRA initiatives. The current administration will likely continue to withdraw from or otherwise roll back certain environmental commitments. Notably, on March 12, 2025, EPA Administrator Lee Zeldin announced initiatives to reconsider regulations addressing power plants, oil and gas, air pollution standards, GHG reporting, wastewater, endangerment findings, environmental justice, and other initiatives. While it is not possible at this time to predict how any such actions may impact our business, such actions, if undertaken, may prompt more activity from state, and local legislative bodies and administrative agencies to pass stricter GHG laws, regulations, and other binding commitments. And in February of 2026, the EPA announced it was eliminating both the Obama-era 2009 Greenhouse Gas (GHG) Endangerment Finding and all subsequent federal GHG emission standards for all vehicles and engines of model years 2012 to 2027 and beyond. As the current administration seeks deregulation, various states and groups of states have adopted or are considering adopting legislation, regulations, or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. Some state courts (including the Montana Supreme Court in Held v. Montana (Mont. 2024)) have rendered decisions imposing additional requirements on regulators and regulated entities with respect to environmental matters.

At the federal level, no comprehensive climate change legislation has been implemented to date. However, the EPA has determined that GHG emissions present a danger to public health and the environment and has adopted regulations under existing provisions of the federal CAA that, among other things: establish that Prevention of Significant Deterioration (“PSD”) construction permit programs and Title V operating permit programs will include reviews for GHG emissions from certain large stationary sources that are also potential major sources of criteria pollutant emissions; require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources; implement CAA emission new source performance standards (“NSPS”) directing the reduction of methane from certain new, modified or reconstructed facilities in the oil and natural gas sector; and together with the U.S. Department of Transportation (“DOT”), implement GHG emissions limits on vehicles manufactured for operation in the U.S. Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations, or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. Some state courts (including the Montana Supreme Court in Held v. Montana (Mont. 2024)) have rendered decisions imposing additional requirements on regulators and regulated entities with respect to environmental matters. At the international level, there exists the United Nations-sponsored “Paris Agreement,” which calls upon nations to limit their GHG emissions through individually determined reduction goals every five years after 2020.

There are also increasing financial risks for fossil fuel producers, as stockholders and bondholders currently invested in fossil-fuel energy companies may elect to shift investments into non-fossil fuel energy related sectors. Institutional lenders who provide financing to fossil-fuel energy companies are beginning to define sustainable lending practices, and financial institutions may adopt policies that limit funding for fossil fuel energy companies, as governmental and nongovernmental institutions focus on addressing climate-related risks in the financial sector. Although we are not an oil or gas producer, it is possible that limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay, or cancellation of drilling programs or development or production activities which could affect the price or availability of certain of our feedstocks.

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Some scientists have concluded that increasing concentrations of GHG in the earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events; if any such effects were to occur, they could have an adverse effect on our operations located throughout the U.S.

Hazardous Substances and Wastes

The Comprehensive Environmental Response, Compensation and Liability Act, as amended (“CERCLA”), also known as the “Superfund” law, and comparable state laws impose liability without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. Such classes of persons include the current and past owners and operators of sites where a hazardous substance was released and companies that disposed or arranged for disposal of hazardous substances at offsite locations, such as landfills. Under CERCLA, these “responsible persons” may be subject to joint and several, strict liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. Separately, it is not uncommon for neighboring landowners and other third parties to file claims under relevant state laws for personal injury and property damage allegedly caused by the release of hazardous substances into the environment. In the course of our operations, we generate wastes or handle substances that may be regulated as hazardous substances, and we could become subject to liability under CERCLA and comparable state laws.

We also may incur liability under the Resource Conservation and Recovery Act, as amended (“RCRA”), and comparable state laws, which impose requirements related to the handling, storage, treatment and disposal of hazardous and non-hazardous wastes. In the course of our operations, we generate petroleum product wastes and ordinary industrial wastes that may be regulated as hazardous wastes. In addition, our operations also generate non-hazardous solid wastes, which are regulated under RCRA and state laws. Historically, our environmental compliance costs under the existing requirements of RCRA and similar state and local laws have not had a material adverse effect on our results of operations, and the cost involved in complying with these requirements is not material.

We currently own or operate, and have in the past owned or operated, properties that for many years have been used for refining and terminal activities. These properties in the past may have been operated by third parties whose treatment and disposal or release of petroleum hydrocarbons and wastes were not under our control. Although we used operating and disposal practices that were standard in the industry at the time, petroleum hydrocarbons or wastes have been released on or under the properties owned or operated by us. These properties and the materials disposed or released on them may be subject to CERCLA, RCRA and analogous state laws. Under such laws, we could be required to remove or remediate previously disposed wastes or property contamination or to perform remedial activities to prevent future contamination.

In addition, new laws and regulations, amendment of existing laws and regulations, reinterpretation of legal requirements, increased governmental enforcement or other developments could significantly increase our operational or compliance expenditures.

Water Discharges

The Federal Water Pollution Control Act of 1972, as amended, also known as the federal Clean Water Act (“CWA”), and analogous state laws impose restrictions and stringent controls on the discharge of pollutants, including oil, into regulated waters. Such discharges are prohibited, except in accordance with the terms of a permit issued by the EPA or the appropriate state agencies. Any unpermitted release of pollutants, including crude oil or hydrocarbon specialty oils as well as refined products, could result in penalties, as well as significant remedial obligations. Spill prevention, control, and countermeasure requirements of federal laws require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture, or leak. Historically, our environmental compliance costs under the existing requirements of the CWA and similar state laws have not had a material adverse effect on our results of operations but these laws and their implementing regulations are subject to change and there can be no assurance that such future costs will not be material.

The primary federal law for oil spill liability is the Oil Pollution Act of 1990, as amended (“OPA”), which addresses three principal areas of oil pollution — prevention, containment and cleanup. The OPA applies to vessels, offshore

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facilities and onshore facilities, including refineries, terminals and associated facilities that may affect waters of the U.S. Under the OPA, responsible parties, including owners and operators of onshore facilities, may be subject to oil cleanup costs and natural resource damages as well as a variety of public and private damages from oil spills. Historically, our past environmental compliance costs under the existing requirements of the OPA have not had a material adverse effect on our results of operations but this law and its implementing regulations are subject to change and there can be no assurance that such future costs will not be material.

Occupational Health and Safety

We are subject to various laws and regulations relating to occupational health and safety, including the federal Occupational Safety and Health Act, as amended (“OSH Act”), and comparable state laws. These laws and regulations strictly govern the protection of the health and safety of employees. In addition, OSHA’s hazard communication standard, the EPA’s community right-to-know regulations under Title III of CERCLA, and similar state statutes require that we maintain information about hazardous materials used or produced in our operations and provide this information to employees, contractors, state and local government authorities and customers. We maintain safety and training programs as part of our ongoing efforts to ensure compliance with applicable laws and regulations. We conduct periodic audits of Process Safety Management (“PSM”) systems at each of our locations subject to the PSM standard. Our compliance with applicable health and safety laws and regulations has required, and continues to require, substantial expenditures. Changes in occupational safety and health laws and regulations or a finding of non-compliance with current laws and regulations could result in additional capital expenditures or operating expenses, as well as civil penalties and, in the event of a serious injury or fatality, criminal charges.

Other Environmental and Maintenance Items

We perform preventive and normal maintenance on our refining and terminal assets and make repairs and replacements when necessary or appropriate. We also conduct inspections of these assets as required by law or regulation.

Insurance

Our operations are subject to certain hazards of operations, including fire, explosion and weather-related perils. We maintain insurance policies, including business interruption insurance for each of our facilities, with insurers in amounts and with coverage and deductibles that we, with the advice of our insurance advisors and brokers, believe are reasonable and prudent. We cannot, however, ensure that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at economical prices. We are not fully insured against certain risks because such risks are not fully insurable, coverage is unavailable, or premium costs, in our judgment, do not justify such expenditures. In addition, a portion of our property coverage is provided by our wholly owned captive insurance company.

Seasonality

The fuel and fuel related products that we manufacture, including asphalt products, are subject to seasonal demand and trends. Asphalt demand is generally lower in the first and fourth quarters of the year, as compared to the second and third quarters, due to the seasonality of the road construction and roofing industries we supply. Demand for gasoline and diesel is generally higher during the summer months than during the winter months due to seasonal increases in highway traffic and agricultural activity. In addition, our natural gas costs can be higher during the winter months, as demand for natural gas as a heating fuel increases during the winter. As a result, our operating results for the first and fourth calendar quarters may be lower than those for the second and third calendar quarters of each year due to seasonality related to these and other products that we produce and sell.

Properties

We own and lease the principal properties listed below. The principal properties which we own, as well as others not listed below, are pledged as collateral under our Collateral Trust Agreement as discussed in Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Master Derivative Contracts and Collateral

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Trust Agreement.” We believe that all properties are suitable for their intended purpose, are being efficiently utilized and provide adequate capacity to meet demand for the next several years.


Property		Business Segment(s)		Acres		Owned / Leased		Location
Shreveport facility		Specialty Products and Solutions		240		Owned		Shreveport, Louisiana
Montana specialty asphalt facility		Montana/Renewables		65		Owned / Leased ⁽¹⁾		Great Falls, Montana
Montana Renewables facility		Montana/Renewables		21		Owned / Leased⁽²⁾		Great Falls, Montana
Princeton facility		Specialty Products and Solutions		208		Owned		Princeton, Louisiana
Cotton Valley facility		Specialty Products and Solutions		77		Owned		Cotton Valley, Louisiana
Burnham terminal		Specialty Products and Solutions		11		Owned		Burnham, Illinois
Karns City facility		Specialty Products and Solutions		225		Owned		Karns City, Pennsylvania
Dickinson facility		Specialty Products and Solutions		28		Owned		Dickinson, Texas
Missouri facility		Specialty Products and Solutions		22		Owned		Louisiana, Missouri
Calumet Packaging facility		Performance Brands		10		Leased		Shreveport, Louisiana
Royal Purple facility		Performance Brands		20		Owned		Porter, Texas

(1)	We lease, with a purchase option, 870 acres of land nearby for strategic expansion.

(2)	Montana Renewables LLC, an unrestricted subsidiary of the Company, leases certain property from the Company.

In addition to the items listed above, we lease or own a number of storage tanks, railcars, warehouses, equipment, land, crude oil loading facilities and precious metals.

Intellectual Property

Our patents relating to our refining operations are not material to us as a whole. Our patents include composition patents that are integral to certain products in the Specialty Products and Solutions segment. We own, have registered or have applied for registration of a variety of tradenames, service marks and trademarks for use in our business. The trademarks, tradenames and design marks under which we conduct our branded business (including Penreco, Orchex, Royal Purple, Bel-Ray and TruFuel) and other trademarks employed in the marketing of our products are integral to our marketing operations. We also license intellectual property rights from third parties. We are not aware of any facts as of the date of this filing which would negatively impact our continuing use of intellectual property or our licensed intellectual property.

Office Facilities

In addition to our principal properties discussed above, as of December 31, 2025, we were a party to a number of cancelable and noncancelable leases for certain properties, including our corporate headquarters in Indianapolis, Indiana. The corporate headquarters lease is for approximately 50,000 square feet of office space. The lease term expires in July 2035. Read Note 4 — “Leases” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” of this Annual Report for additional information regarding our leases.

While we may require additional office space as our business expands, we believe that our existing facilities are adequate to meet our needs for the immediate future and that additional facilities will be available on commercially reasonable terms as needed.

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Human Capital Management

We believe that our employees are significant contributors to our success and the future success of our Company, which depends on our ability to attract, retain and motivate qualified personnel. The skills, experience and industry knowledge of key employees significantly benefit our operations and performance.

As of February 27, 2026, the Company employed approximately 1,540 people who provide direct support to our operations. Of these employees, approximately 600 are covered by collective bargaining agreements.

Employees at the following locations are covered by the following separate collective bargaining agreements:


Facility	Union	Expiration Date
Cotton Valley	International Union of Operating Engineers	November 19, 2026
Princeton	International Union of Operating Engineers	August 20, 2028
Dickinson	International Union of Operating Engineers	December 12, 2028
Shreveport	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	April 30, 2026
Missouri	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	April 30, 2028
Karns City	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	January 31, 2027
Great Falls	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	July 31, 2026

None of the employees at the Calumet Packaging facility, the Royal Purple facility or at the Burnham terminal are covered by collective bargaining agreements. We consider our employee relations to generally be good, with no history of work stoppages.

Compensation and Benefits

We have demonstrated a history of investing in our workforce by offering competitive salaries, fair wages and comprehensive benefits. To foster a stronger sense of ownership and align the interests of our personnel with stockholders, we provide short-term and long-term incentive programs that include short-term cash bonus awards under our Cash Incentive Plan and restricted stock unit awards under our Long-Term Incentive Plan. Awards under these incentive programs are subject to individual and company performance factors. Furthermore, we offer comprehensive benefits to our full-time employees working 30 hours or more per week, including long-term disability coverage, comprehensive health insurance, including vision and dental, employee Health Savings Accounts, including contributions to these accounts by us, competitive paid time off and sick leave programs, and student loan repayment matching opportunities. In addition, we provide a 401(k) retirement savings plan to assist our eligible employees in saving for their retirement. To be an employer of choice and maintain the strength of our workforce, we consistently assess the current business environment and labor market to refine our compensation and benefits programs and other resources available to our personnel.

Workforce Health and Safety

The safety of our employees is a core tenet of our values, and our safety goal is zero incidents and zero injuries. A strong safety culture reduces risk, enhances productivity and builds a strong reputation in the communities in which we operate. We have earned a reputation as a safe and an environmentally responsible operator through continuous improvement in our safety performance. This makes us more attractive for current and new employees.

We invest in safety training and coaching, promote risk assessments and encourage visible safety leadership. Employees are empowered and expected to stop or refuse to perform a job if it is not safe or cannot be performed safely. We sponsor emergency preparedness programs, conduct regular audits to assess our performance and celebrate our successes in which we acknowledge employees and contractors alike who have exhibited strong safety leadership during

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the course of the year. These many efforts combine to create a culture of safety throughout the company and provide a positive influence on our contractor community.

Inclusion and Workplace Culture

We are committed to maintaining a culture where inclusion and belonging are core philosophies across our operations, including, but not limited to, our decisions around recruitment, promotion, transfer, leaves of absence, compensation, opportunities for career support and advancement, job performance and other relevant job-related criteria. We are committed to making opportunities for development and progress available to all employees so their talents can be fully developed to maximize our and their success. We believe that creating an environment that cultivates a sense of belonging requires encouraging employees to continue to educate themselves about each other’s experiences, and we strive to promote the respect and dignity of all persons. We also believe it is important that we foster education, communication and understanding about inclusion and belonging.

Address, Internet Website and Availability of Public Filings

Our principal executive offices are located at 1060 N Capitol Ave., Suite 6-401, Indianapolis, Indiana, 46204 and our telephone number is (317) 328-5660. Our website is located at www.calumet.com.

Our Securities and Exchange Commission (“SEC”) filings are available on our website as soon as reasonably practicable after we electronically file such material with, or furnish such material to, the SEC. We make available, free of charge on our website, our Annual Reports on Form 10-K, our Quarterly Reports on Form 10-Q, our Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). These documents are located on our website at www.calumet.com by selecting the “Investor Relations” link, and then selecting the “Financial Reporting” link and then selecting the “SEC Filings” link. We also make available, free of charge on our website, our charters for the Audit Committee, Compensation Committee, Nominating and Governance Committee, Risk Committee, and Strategy and Growth Committee, and our Code of Business Conduct and Ethics. We intend to satisfy the disclosure requirement under Item 5.05 of Form 8-K relating to amendments to or waivers from any provision of the Code of Business Conduct and Ethics applicable to our executive officers and directors by posting such information on our website. These documents are located on our website at www.calumet.com by selecting the “Investor Relations” link, then selecting the “Governance” link, and then selecting “Governance Documents.” All reports and documents filed with the SEC are also available via the SEC’s website, www.sec.gov.

The above information is available to anyone who requests it and is free of charge either in print from our website or upon request by contacting Investor Relations using the contact information listed above. Information on our website is not incorporated into this Annual Report or our other securities filings and is not a part of them.

Item 1A. Risk Factors

An investment in our common stock involves a significant degree of risk. Before you invest in our common stock, you should carefully consider the risk factors discussed or referenced below. If any of the risks discussed below were actually to occur, our business, financial position or results of operations could be materially adversely affected. The disclosures in this section reflect our beliefs and opinions as to factors that could materially and adversely affect us in the future. References to past events are provided by way of example only and are not intended to be a complete listing or a representation as to whether or not such factors have occurred in the past.

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Risks Related to our Business

Results of Operations and Financial Condition

Our business depends on supply and demand fundamentals, which can be adversely affected by numerous macroeconomic factors outside of our control and which may in turn impact our operational and financial performance, including our ability to execute our business strategies in the expected time frame.

Such macroeconomic factors include:

●

reduction in the demand for, and the marketability of, our specialty products due to governmental regulations;

●

increased volatility in product margins;

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the ability or willingness of our suppliers to provide raw materials, equipment, services or supplies for our operations or otherwise fulfill their contractual obligations, which could reduce our production levels or otherwise impact our ability to deliver refined or finished lubricant products timely or at all;

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the ability or willingness of our customers to fulfill their contractual obligations or any material reduction in, or loss of, orders or revenue from our customers;

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occurrence of operational hazards, including terrorism, cyberattacks or domestic vandalism, as well as information system failures or communication network disruptions;

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increased cost and reduced availability of capital for growth or maintenance expenditures;

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availability and operability of terminals, tankage and pipelines that store and transport our feedstocks and products;

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the amount of our borrowing base under our revolving credit facility and our ability to issue letters of credit or the requirement that we post substantial amounts of credit support;

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the impairment of our long-lived assets or goodwill, which could reduce our earnings;

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the impact of any economic downturn, recession, inflationary pressures, increases in interest rates, government shutdowns, or other disruptions of the U.S. and global economies and financial and commodity markets; and

●

political tensions, conflicts and war, such as the ongoing conflicts in Ukraine, Venezuela and the Middle East.

In many cases, specialty products are produced from intermediates that ultimately originate from crude oil. Typically, we enjoy a cost advantage from processing crude oil into intermediates that are used as specialty feedstocks. This process also creates fuels and other by-products, which carry a margin to crude prices. Typically, the total margin of fuels and other by-products to crude oil is a positive, but in extreme demand scenarios this cost advantage can turn into a short-term disadvantage. When the margin between product sales prices and feedstock costs tightens, our earnings, profitability and cash flows are negatively impacted.

A widely used benchmark to track margins in the fuel products industry is the Gulf Coast 2/1/1 crack spread (“Gulf Coast crack spread”), which represents the gross margin assuming that two barrels of a benchmark crude oil are converted, or cracked, into one barrel of gasoline and one barrel of diesel. The Gulf Coast 2/1/1 crack spread ranged from a high of

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$34.05 per barrel to a low of $16.70 per barrel during 2025 and averaged $24.04 per barrel during 2025 compared to an average of $17.02 in 2024.

Our actual fuels product margins may vary from the Gulf Coast crack spread due to the actual crude oil used and products produced, transportation costs, regional differences, and the timing of the purchase of the feedstock and sale of the refined products, but we use the Gulf Coast crack spread as an indicator of the volatility and general levels of fuels refining margins.

Our specialty product margins are influenced by the price of our feedstocks, many of which are commodities. If feedstock prices increase, our margins would fall unless we are able to pass through these price increases to our customers.

Our hedging activities may not be effective in reducing our exposure to commodity price risk and may reduce our earnings, profitability and cash flows.

From time to time, we utilize derivative financial instruments related to the future price of crude oil, natural gas and refined products to manage expected outcomes involving commodity price risk. We typically do not enter into derivative financial instruments to reduce our exposure to prices of the specialty products we sell as there is no established derivative market for such products.

We limit our derivative transactions to only a portion of the volume of our expected purchase and sales requirements and, as a result, we will continue to have direct commodity price exposure to the unhedged portion of our expected purchase and sales requirements. Thus, we could be exposed to significant increases in commodity prices, which would increase the cost for a portion of our feedstock purchases.

Our actual future purchase and sales requirements may be significantly higher or lower than we estimate at the time we enter into derivative transactions for such period. If the actual amount is higher than we estimate, we will have greater commodity price exposure than we intended. If the actual amount is lower than the amount that is subject to our derivative financial instruments, we might be forced to satisfy all or a portion of our derivative transactions without the benefit of the cash flow from our sale or purchase of the underlying physical commodity, which may result in a substantial diminution of our liquidity. As a result, our hedging activities may not be as effective as we intend in reducing our exposure to price risk. In addition, our hedging activities are subject to the risks that a counterparty may not perform its obligations under the applicable derivative instrument, the terms of the derivative instruments are imperfect, and our risk management policies and procedures are not properly followed. It is possible that the steps we take to monitor our derivative financial instruments may not detect and prevent violations of our risk management policies and procedures, particularly if deception or other intentional misconduct is involved.

Decreases in the price of inventory and products may lead to a reduction in the borrowing base under our revolving credit facility and our ability to issue letters of credit or the requirement that we post substantial amounts of cash collateral for derivative instruments, which could adversely affect our liquidity, financial condition and our ability to make payments on our debt obligations.

We rely on borrowings and letters of credit under our revolving credit facility to purchase feedstocks for our facilities for use in our operations. The borrowing base under our revolving credit facility is determined weekly or monthly depending upon availability levels or the existence of a default or event of default. Reductions in the value of our inventories as a result of lower crude oil prices could result in a reduction in our borrowing base, which would reduce the amount of financial resources available to meet our operating requirements. If, under certain circumstances, our available capacity under our revolving credit facility falls below certain threshold amounts, or a default or event of default exists, then our cash balances in a dominion account established with the administrative agent will be applied on a daily basis to our outstanding obligations under our revolving credit facility. In addition, decreases in the price of crude oil or increases in crack spreads may require us to post substantial amounts of cash collateral to our hedging counterparties in order to maintain our derivative instruments. If, due to our financial condition or other reasons, the borrowing base under our revolving credit facility decreases, we are limited in our ability to issue letters of credit or we are required to post substantial amounts of cash collateral to our hedging counterparties, our liquidity, financial condition and our ability to make payments on our debt obligations could be materially and adversely affected. Read Part II, Item 7 “Management’s Discussion and

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Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Debt and Credit Facilities” for additional information.

We depend on certain third-party pipelines for transportation of feedstocks and products, and if these pipelines become unavailable to us, our revenues and cash available for payment of our debt obligations could decline.

Our Shreveport facility is interconnected to a pipeline that supplies a portion of its crude oil and a pipeline that ships a portion of its refined fuel products to customers, such as pipelines operated by subsidiaries of Enterprise Products Partners L.P. and Plains. Our Great Falls facility receives crude oil through the Front Range pipeline system via the Bow River Pipeline in Canada. Since we do not own or operate any of these pipelines, their continuing operation is not within our control.

The unavailability of any of these third-party pipelines for the transportation of crude oil or our refined fuel products, because of acts of God, accidents, earthquakes or hurricanes, government regulation, terrorism or other third-party events, could lead to disputes or litigation with certain of our suppliers or a decline in our sales, net income and cash available for payments of our debt obligations.

The price volatility of utility services may result in decreases in our earnings, profitability and cash flows.

The volatility in costs of natural gas and other utility services, principally electricity, used by our facilities and other operations affect our net income and cash flows. Natural gas and utility prices are affected by factors outside of our control, such as supply and demand in both local and regional markets. Natural gas prices have historically been volatile.

For example, daily prices for natural gas as reported on the NYMEX ranged between $5.29 and $2.70 per million British thermal unit (“MMBtu”) in 2025, and between $3.95 and $1.58 per MMBtu in 2024. Typically, electricity prices fluctuate with natural gas prices. Future increases in natural gas and utility prices may have a material adverse effect on our results of operations. However, international natural gas prices have been more volatile, and more expensive, than domestic prices, which can provide a competitive advantage to domestic plants. This dynamic means that market product prices may increase more than our utility costs, creating higher margins when natural gas and utility costs increase less than international competitors’ utility prices. Natural gas and utility costs constituted approximately 14.0% and 10.3% of our total operating expenses included in cost of sales for the years ended December 31, 2025 and 2024, respectively. As prices and industry competitive dynamics change, it could adversely affect our profitability and the amount of cash available for payments of our debt obligations.

Our facilities incur operating hazards, and the potential limits on insurance coverage could expose us to potentially significant liability costs.

Our facilities are subject to certain operating hazards, and our cash flow from those operations could decline if any of our facilities experience a major accident, pipeline rupture or spill, explosion or fire, is damaged by severe weather or other natural disaster, or otherwise is forced to curtail its operations or shut down. These operating hazards could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property and equipment, and pollution or other environmental damage. One or more of these developments may result in significant curtailment or suspension of our related operations.

Although we maintain insurance policies, including personal and property damage and business interruption insurance for each of our facilities, we cannot ensure that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or significant interruption of operations. Our business interruption insurance will not apply unless a business interruption exceeds 60 days. Furthermore, we may be unable to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies have increased and could escalate further. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. In addition, we are not fully insured against all risks incident to our business because certain risks are not fully insurable, coverage is unavailable, or premium costs, in our judgment, do not justify such expenditures. For example, we are not insured for all environmental liabilities, including, but not limited to, product spills and other releases at all of our facilities. If we were to incur a

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significant liability for which we are not insured or fully insured, it could affect our financial condition and diminish our ability to make payments of our debt obligations.

Downtime for maintenance at our refineries and facilities will reduce our revenues and could limit our ability to make payments of our debt obligations.

Our facilities consist of many processing units, a number of which have been in operation for extended periods of time. One or more of the units have in the past required, and may in the future require, additional unscheduled downtime for unanticipated maintenance or repairs that are more frequent than our scheduled turnaround for each unit every one to five years. Scheduled and unscheduled maintenance reduce our revenues and increase our operating expenses during the period of time that our processing units are not operating and could limit our ability to make payments of our debt obligations.

An impairment of our long-lived assets or goodwill could reduce our earnings or negatively impact our financial condition and results of operations.

We continually monitor our business, the business environment and the performance of our operations to determine if an event has occurred that indicates that a long-lived asset or goodwill may be impaired. If an event occurs, which is a determination that involves judgment, we may be required to utilize cash flow projections to assess our ability to recover the carrying value based on the ability to generate future cash flows. Our long-lived assets and goodwill impairment analyses are sensitive to changes in key assumptions used in our analysis, such as expected future cash flows, the degree of volatility in equity and debt markets and our stock price. If the assumptions used in our analysis are not realized, it is possible a material impairment charge may need to be recorded in the future.

We cannot accurately predict the amount and timing of any impairment of long-lived assets or goodwill. Further, as we continue to develop our strategy regarding certain of our non-core assets, we will need to continue to evaluate the carrying value of those assets. Any additional impairment charges that we may take in the future could be material to our results of operations and financial condition.

Competition in our industries is intense, and an increase in competition in the markets in which we sell our products could adversely affect our earnings and profitability.

We compete with a broad range of companies within our industries. Because of some of our competitors’ geographic diversity, larger and more complex refineries, integrated operations and greater resources, some of our competitors may be better able to withstand volatile market conditions, to obtain crude oil and renewable feedstocks in time of shortage and to bear the economic risks inherent in all areas of the industries.

In addition, we compete with other industries that provide alternative means to satisfy the energy and fuel requirements of our industrial, commercial and individual consumers. The more successful these alternatives become as a result of governmental regulations, technological advances, consumer demand, improved pricing or otherwise, the greater the impact on pricing and demand for our products and our profitability. There are presently significant governmental and consumer pressures to increase the use of alternative fuels in the United States. While in some areas of our business these pressures are helpful, in other areas they can pose a significant risk.

Substantially all of our operating personnel at our Shreveport, Great Falls, Princeton, Cotton Valley, Karns City, Dickinson and Missouri facilities are employed under collective bargaining agreements. If we are unable to renegotiate these agreements as they expire, any work stoppages or other labor disturbances at these facilities could have an adverse effect on our business and impact our ability to make payments of our debt obligations. In addition, employees who are not currently represented by labor unions may seek union representation in the future, and any renegotiation of current collective bargaining agreements may result in terms that are less favorable to us. Furthermore, our actions or responses

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to any such negotiations, labor disputes, strikes or work stoppages could negatively impact how we are perceived and the impact on our reputation could have adverse effects on our business.

Our method of valuing inventory may result in decreases in net income.

The nature of our business requires us to maintain substantial quantities of inventories. Some of our inventory is commodity based, providing us little control over the changing market value of these inventories. Because our inventory is valued at the lower of cost or market (“LCM”) value, if the market value of our inventory were to decline to an amount less than our cost, we would record a write-down of inventory and a non-cash charge to cost of sales. In periods of decreasing crude oil or refined product prices, our inventory valuation methodology has resulted in and may in the future result in decreases in net income.

We depend on key personnel for the success of our business and the loss of those persons could adversely affect our business and our ability to make payments of our debt obligations.

The loss of the services of any member of senior management or key employee could have an adverse effect on our business and reduce our ability to make payments of our debt obligations. Our success in hiring, attracting and retaining senior management and other experienced and highly skilled employees will depend in part on our ability to provide competitive compensation packages and a high-quality work environment and maintain a desirable corporate culture. We may not be able to locate or employ on acceptable terms qualified replacements for senior management or other key employees if their services were no longer available. We do not maintain any key-man life insurance.

We are subject to cybersecurity risks and other cyber incidents resulting in disruption.

Threats to information technology systems associated with cybersecurity risks and cyber incidents or attacks continue to grow. We depend on information technology systems to run our business. In addition, our use of the internet, cloud services and other public networks, exposes our business and that of other third parties with whom we do business to cybersecurity threats. Geopolitical tensions or conflicts may further heighten the risk of cybersecurity incidents. Additionally, the emergence and maturation of artificial intelligence capabilities may also lead to new and/or more sophisticated methods of attack, including fraud that relies upon “deep fake” impersonation technology or other forms of generative automation that may scale up the efficiency or effectiveness of cybersecurity attacks. Such incidents could lead to unauthorized access to data and systems, intentional or inadvertent releases of confidential information, including personally identifiable information, corruption of data and disruption of critical systems and operations. Despite the security measures we have in place and any additional measures we may implement in the future, our facilities and systems, and those of our third-party service providers, could be vulnerable to security breaches, computer viruses, ransomware attacks, phishing attacks, inadvertent data disclosures, programming errors, human errors or malfeasance, acts of vandalism or other events. Moreover, these threats are constantly evolving, thereby making it more difficult to successfully defend against them or to implement adequate preventive measures. We may not have the current capability to detect certain vulnerabilities, or may not detect them in a timely manner, which may allow those vulnerabilities to persist in our systems over long periods of time. We have experienced in the past, and may continue to experience attempts, to gain unauthorized access to our information systems. Any disruption of our systems or cybersecurity incident or event resulting in the misappropriation, loss or other unauthorized disclosure of confidential information, whether by us directly or our third-party service providers, could damage our reputation, expose us to the risks of litigation and liability or regulatory fines, penalties or intervention, disrupt our business, require us to incur significant costs to remediate damage resulting from the incident or improve our information technology systems, or otherwise affect our results of operations, which could materially and adversely affect our business, results of operations or financial condition. In addition, as cybersecurity incidents continue to evolve in magnitude and sophistication, and our reliance on digital technologies continues to grow, we have expended and expect to continue to expend additional resources in order to continue to enhance our cybersecurity measures and to investigate and remediate any digital systems, related infrastructure, technologies and network security vulnerabilities. While we carry cyber insurance, we cannot be certain that our coverage will be adequate for liabilities actually incurred, that insurance will continue to be available to us on economically reasonable terms, or at all, or that any insurer will not deny coverage as to any future claim.

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We are also subject to an evolving landscape of laws and regulations in a range of jurisdictions governing the handling of information and the operation of information systems, including those relating to privacy, cybersecurity and data protection. Costs associated with compliance with these laws and regulations may increase over time and failure to comply with these obligations could result in investigations, litigation, fines, penalties, judgments or other proceedings which could have a material impact on our financial results.

AI presents risks and challenges that can impact our business.

Artificial intelligence (“AI”) presents risks and challenges that could impact our business, including breaches of privacy or security incidents related to the use of AI. We are integrating AI tools into our systems, and our third-party service providers as well as our competitors may also develop or use such tools. AI may become more important to our operations or to our future growth over time. There can be no assurance that we will realize the desired or anticipated benefits, or any benefits, and we may not properly implement such technology. In addition, we or our AI service providers may not meet existing or rapidly evolving regulatory or industry standards with respect to privacy and data protection, compliance, and transparency, among others, which could inhibit our or our service providers’ ability to maintain an adequate level of functionality or service. Our service providers may also incorporate AI into their services without disclosing such use to us, or fail to disclose risks presented by their use of AI. There is a risk that AI tools used by us or by our service providers could produce inaccurate or unexpected results or behaviors that could harm our business, customers or reputation. Our competitors or other third parties may incorporate AI in their business operations more quickly or more successfully than we do, which may negatively impact our ability to compete effectively. Additionally, the complex and rapidly evolving landscape around AI may expose us to claims, inquiries, demands and proceedings by private parties and regulatory authorities and subject us to legal liability as well as reputational harm. New laws and regulations are being adopted in various jurisdictions globally, including in the United States and European Union, and existing laws and regulations may be interpreted in ways that would affect our business operations and the way in which we use AI. Any of these outcomes could impair our ability to compete effectively, damage our reputation, result in the loss of our or our customers’ property or information and/or materially adversely affect our business, financial condition and results of operations.

Indebtedness; Financing

Our arrangement with J. Aron exposes us to J. Aron-related credit and performance risk as well as potential refinancing risks.

In January 2024, the Partnership and J. Aron & Company (“J. Aron”) entered into a Monetization Master Agreement (the “Master Agreement”), a related Financing Agreement (the “Financing Agreement”) and Supply and Offtake Agreement (together with the Master Agreement and the Financing Agreement, the “Shreveport Supply and Offtake Agreement”). Pursuant to the Shreveport Supply and Offtake Agreement, J. Aron agreed to, among other things, purchase from the Company, or extend to the Company, financial accommodations secured by crude oil and finished products located at our Shreveport facility and from time to time, up to maximum volumes specified for crude oil and categories of finished products, subject to the Company’s repurchase obligations with respect thereto.

When we executed the Shreveport Supply and Offtake Agreement, the inventories associated with such agreement were taken out of our revolving credit facility borrowing base. Should an early termination event occur, pursuant to the terms of the Supply and Offtake Agreement, we would need to seek alternative sources of financing, such as putting the inventory associated with the Shreveport Supply and Offtake Agreement back into our revolving credit facility, to meet our obligation to repurchase the inventory at then current market prices. In addition, upon expiration of the Shreveport Supply and Offtake Agreement, the cost of repurchasing the inventory may be at higher prices than we sold the inventory. If the price of the applicable products is well above the price at which we sold the inventory, we would have to pay more for the inventory than the price we sold the inventory. If this is the case at the time of termination and we are unable to include the inventory associated with the Shreveport Supply and Offtake Agreement in our borrowing base, we could suffer a significant reduction in liquidity if J. Aron terminates the Shreveport Supply and Offtake Agreement and we have to repurchase the inventories.

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We have a substantial amount of indebtedness, which may adversely affect our cash flow and our ability to operate our business.

We had approximately $2.3 billion of outstanding indebtedness as of December 31, 2025, including $815.4 million of indebtedness at MRL, an unrestricted subsidiary of the Company and for which the parent Company is not a guarantor. We have availability for borrowings of approximately $242.5 million under our senior secured revolving credit facility. We have the ability to incur additional debt, including the ability to borrow up to an aggregate principal amount of $650.0 million at any time, subject to borrowing base limitations, under our revolving credit facility. A tranche of the revolving credit facility includes a $50.0 million senior secured first loaned in and last to be repaid out (“FILO”) revolving credit facility. In addition, as of February 27, 2026, MRL had approximately $815.4 million of outstanding indebtedness under a loan guarantee agreement (the “DOE Facility”) with the U.S. Department of Energy (“DOE”) and MRL has the ability to draw additional tranches of up to $624.6 million through the anticipated completion of this project in 2028. Calumet is not a guarantor of MRL indebtedness. Our substantial indebtedness could adversely affect our results of operations, business and financial condition, and our ability to meet our debt obligations. In addition, our level of indebtedness could have important consequences to us, including the following:

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our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on favorable terms;

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covenants contained in our existing and future credit and debt arrangements will require us to meet financial tests that may affect our flexibility in planning for and reacting to changes in our business, including possible acquisition opportunities;

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we will need a substantial portion of our cash flow to make principal and interest payments on our indebtedness, reducing the funds that would otherwise be available for operations, future business opportunities and payments of our debt obligations;

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our ability to execute our acquisition and divestiture strategy; and

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our debt level will make us more vulnerable than our competitors with less debt to competitive pressures or a downturn in our business or the economy in general.

Any of these factors could result in a material adverse effect on our business, financial conditions, results of operations, business prospects and ability to satisfy our obligations under our senior notes, revolving credit facility and the DOE Facility.

Our ability to service our indebtedness will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our current or future indebtedness, we will be forced to take actions such as reducing or delaying our business activities, acquisitions, investments and/or capital expenditures, selling assets, restructuring or refinancing our indebtedness, or seeking additional equity capital or bankruptcy protection. We may not be able to effect any of these remedies on satisfactory terms, or at all. Read Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Debt and Credit Facilities” for additional information regarding our indebtedness.

Our financing arrangements contain operating and financial provisions that restrict our business and financing activities.

The operating and financial restrictions and covenants in our financing arrangements, including our revolving credit facility, DOE Facility, indentures governing each series of our outstanding senior notes and master derivative contracts,

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do currently restrict, and any future financing agreements could restrict, our ability to finance future operations or capital needs or to engage, expand or pursue our business activities, including restrictions on our ability to, among other things:

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sell assets, including equity interests in our subsidiaries;

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redeem or repurchase any subordinated debt and, in the case of the 9.25% Senior Secured First Lien Notes due 2029 (the “2029 Secured Notes”), our unsecured notes;

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incur or guarantee additional indebtedness or issue preferred stock;

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create or incur certain liens;

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make certain acquisitions and investments;

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redeem or repay other debt or make other restricted payments;

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enter into transactions with affiliates;

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enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us;

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create unrestricted subsidiaries;

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enter into sale and leaseback transactions;

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enter into a merger, consolidation or transfer or sale of assets, including equity interests in our subsidiaries; and

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engage in certain business activities.

Our revolving credit facility also contains a springing financial covenant which provides that only if our availability to borrow loans under the revolving credit facility falls below the sum of (a) the greater of (i) (x) 15% of the borrowing base then in effect at any time that the refinery asset borrowing base component is greater than $0 and (y) 10% of the borrowing base then in effect at any time that the refinery asset borrowing base component is equal to $0 and (ii) $45.0 million (which amount is subject to certain increases) plus (b) the amount of FILO Loans (as defined in the Credit Agreement) outstanding, then we will be required to maintain as of the end of each fiscal quarter a Fixed Charge Coverage Ratio (as defined in the Credit Agreement) of at least 1.0 to 1.0. As of December 31, 2025, the Company was in compliance with all covenants under the revolving credit facility.

Our existing indebtedness imposes, and any future indebtedness may impose, a number of covenants on us regarding collateral maintenance and insurance maintenance. As a result of these covenants and restrictions, we will be limited in the manner in which we conduct our business, and we may be unable to engage in favorable business activities or finance future operations or capital needs.

Our ability to comply with the covenants and restrictions in our various financing arrangements, including our revolving credit facility, the DOE Facility, our secured hedge agreements and the indentures governing our senior notes may be materially adversely affected by events beyond our control.

If market or other economic conditions deteriorate, our ability to comply with these covenants and restrictions may be impaired. A failure to comply with the covenants, ratios or tests in our revolving credit facility, the DOE Facility, our secured hedge agreements, the indentures governing our senior notes or any other current or future indebtedness could result in an event of default under our revolving credit facility, our secured hedge agreements, the indentures governing our senior notes or our future indebtedness, which, if not cured or waived, could have a material adverse effect on our

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business, financial condition and results of operations. Among other things, in the event of any default on our indebtedness, our debt holders and lenders:

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will not be required to lend any additional amounts to us;

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could elect to declare all borrowings outstanding, together with accrued and unpaid interest and fees, to be due and payable;

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could elect to require that all obligations accrue interest at the default rate, if such rate has not already been imposed;

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may have the ability to require us to apply all of our available cash to repay these borrowings;

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may prevent us from making debt service payments under our other agreements, any of which could result in an event of default under our notes; or

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in the event of a default by us or our restricted subsidiaries, could foreclose on the collateral pledged pursuant to the terms of the revolving credit facility or the indenture and security documents governing the 2029 Secured Notes, respectively.

If our existing indebtedness were to be accelerated, there can be no assurance that we would have, or be able to obtain, sufficient funds to repay such indebtedness in full. Even if new financing were available, it may be on terms that are less attractive to us than our then existing credit facility or it may not be on terms that are acceptable to us. In addition, our obligations under our revolving credit facility are secured by a first priority lien on our accounts receivable, inventory and substantially all of our cash; our obligations under our secured hedge agreements and the BP Purchase Agreement are secured by a lien on certain of our real property, plant and equipment, fixtures, intellectual property, certain financial assets, certain investment property, commercial tort claims, chattel paper, documents, instruments and proceeds of the forgoing (including proceeds of hedge agreements); and the 2029 Secured Notes are secured by a first-priority lien on all of the fixed assets that secure our obligations under our secured hedge agreements, and if we are unable to repay our indebtedness under the revolving credit facility, the 2029 Secured Notes or satisfy the payment obligations under our secured hedge agreements or the payment obligations under the BP Purchase Agreement or obtain waivers of such defaults, then the lenders under our revolving credit facility, the counterparties to such agreements, and the holders of the 2029 Secured Notes could seek to foreclose on these assets. Read Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Debt and Credit Facilities,” “— Short-Term Liquidity,” “— Long-Term Financing” and “— Master Derivative Contracts and Collateral Trust Agreement” for additional information regarding our long-term debt.

An increase in interest rates will cause our debt service obligations to increase.

Borrowings under our revolving credit facility bears interest at a rate based on the daily Secured Overnight Financing Rate (“SOFR”). As of December 31, 2025, we had $94.6 million outstanding borrowings under our revolving credit facility and $75.2 million in standby letters of credit were issued under our revolving credit facility. The foregoing interest rates are subject to adjustment based on fluctuations in daily SOFR or the prime rate, as applicable. An increase in the interest rates associated with our floating-rate debt would increase our debt service costs and affect our results of operations. In addition, an increase in interest rates could adversely affect our future ability to obtain financing or materially increase the cost of any additional financing.

There is no restriction in our amended and restated certificate of incorporation or bylaws on the ability of us to enter into a transaction which would trigger the change of control provisions of our revolving credit facility agreement, the indentures governing our senior notes, our Collateral Trust Agreement, and our Supply and Offtake Agreement. Certain

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events relating to a change of control of us and our operating subsidiaries would constitute an event of default under our revolving credit facility, our Collateral Trust Agreement and our Supply and Offtake Agreement. In addition, an event of default under our revolving credit facility would likely constitute an event of default under the indentures governing our senior notes, our master derivatives contracts and the BP Purchase Agreement. As a result, upon a change of control event, we may be required to immediately repay the outstanding principal, any accrued interest on and any other amounts owed by us under our revolving credit facility, the senior notes and the Supply and Offtake Agreement and the outstanding payment obligations under our master derivatives contracts and the BP Purchase Agreement. The source of funds for these repayments would be our available cash or cash generated from other sources and there can be no assurance that we would have, or be able to obtain, sufficient funds to repay such indebtedness and other payment obligations in full.

In addition, our obligations under our revolving credit facility are secured by a first-priority lien on our accounts receivable, inventory and substantially all of our cash; our 2029 Secured Notes are secured by a first-priority lien on all of the fixed assets that secure our obligations under our secured hedge agreements; and our obligations under our master derivatives contracts and the BP Purchase Agreement are secured by a first-priority lien on our and our subsidiaries’ real property, plant and equipment, fixtures, intellectual property, certain financial assets, certain investment property, commercial tort claims, chattel paper, documents, instruments and proceeds of the forgoing (including proceeds of hedge agreements). If we are unable to repay our indebtedness under the revolving credit facility, the 2029 Secured Notes, or satisfy the payment obligations under our master derivative contracts or the payment obligations under the BP Purchase Agreement or obtain waivers of such defaults, then the lenders under our revolving credit facility, the holders of our 2029 Secured Notes, the derivative counterparties under our master derivative contracts and BP, respectively, would have the right to foreclose on those assets, which would have a material adverse effect on us.

Capital Projects and Future Growth

We make capital expenditures in our facilities to maintain their reliability and efficiency. If we are unable to complete capital projects at their expected costs and/or in a timely manner, or if the market conditions assumed in our project economics deteriorate, results of operations or cash flows could be adversely affected.

Delays or cost increases related to the engineering, procurement and construction of new facilities, expansions (such as the MaxSAF^TM project), or improvements and repairs to our existing facilities and equipment, could have a material adverse effect on our business, financial condition, results of operations or our ability to make payments on our debt obligations. Such delays or cost increases may arise as a result of unpredictable factors in the marketplace, many of which are beyond our control, including:

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denial or delay in obtaining regulatory approvals and/or permits;

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changes in government regulations, including environmental and safety regulations;

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unplanned increases in the cost of equipment, materials or labor;

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disruptions in transportation of equipment and materials;

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severe adverse weather conditions, natural disasters or other events (such as equipment malfunctions, explosions, fires or spills) affecting our facilities, or those of our vendors and suppliers;

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shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;

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market-related increases in a project’s debt or equity financing costs; and/or

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nonperformance or declarations of force majeure by, or disputes with, our vendors, suppliers, contractors or sub-contractors.

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Equipment, even if properly maintained, may require significant capital expenditures and expenses to keep it operating at optimum efficiency.

Any one or more of these occurrences noted above could have a significant impact on our business or subject us to significant cost overruns. If we were unable to make up the delays or to recover the related costs, or if market conditions change, we may not realize the anticipated benefits of our capital projects and it could materially and adversely affect our financial position, results of operations or cash flows and, as a result, our ability to make payments of our debt obligations.

From time to time, we may seek to divest portions of our business, which could materially affect our results of operations and result in disruption to other parts of the business.

We may dispose of portions of our current business or assets, based on a variety of factors and strategic considerations, consistent with our strategy of preserving liquidity and streamlining our business to better focus on the advancement of our core business. We expect that any potential divestitures of assets will also provide us with cash to reinvest in our business and repay indebtedness. These dispositions, together with any other future dispositions we make, may involve risks and uncertainties, including disruption to other parts of our business, potential loss of employees, customers or revenue, exposure to unanticipated liabilities or result in ongoing obligations and liabilities to us following any such divestiture. In addition, any such divestitures may not yield the targeted improvements in our business. Any of the foregoing could adversely affect our financial condition and results of operations or cash flows and, as a result, our ability to make payments of our debt obligations.

Environmental and Regulatory Matters

We may incur significant environmental remediation costs and liabilities in the operation of our refineries, facilities, terminals and related facilities.

The operation of our refineries, blending and packaging sites, terminals, and related facilities subject us to the risk of incurring significant environmental remediation costs and liabilities due to our handling of petroleum hydrocarbons and wastes or hazardous substances or wastes, because of air emissions and water discharges related to our operations and activities, and as a result of historical operations and waste disposal practices at our facilities or in connection with our activities, some of which may have been conducted by prior owners or operators. We could incur significant remedial costs in the cleanup of any petroleum hydrocarbons or wastes or hazardous substances or wastes that may have been released on, under or from the properties owned or operated by us. While we believe we have adequately reserved for these possibilities, such costs and liabilities are difficult to predict and could exceed the amount reserved.

Some environmental laws may impose joint and several, strict liability for releases of petroleum hydrocarbons and wastes or hazardous substances or wastes, which means in some situations, we could be exposed to liability as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior operators or other third parties. Private parties, including the owners of properties adjacent to our operations and facilities where our petroleum hydrocarbons or wastes or hazardous substances or wastes are taken for reclamation or disposal, may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. We may not be able to recover some or any of these costs from insurance or other sources of indemnity. To the extent that the costs associated with meeting any or all of these requirements are significant and not adequately secured or indemnified for, there could be a material adverse effect on our business, financial condition and results of operations or cash flows and, as a result, our ability to make payments of our debt obligations.

We are subject to operational compliance with stringent environmental and occupational health and safety laws and regulations that may expose us to significant costs and liabilities.

Our refining, blending and packaging site, terminal and related facility operations are subject to stringent federal, regional, state and local laws and regulations governing worker health and safety, the discharge of materials into the environment and environmental protection. These laws and regulations impose legal requirements that are applicable to our operations, including the obligation to obtain permits to conduct regulated activities, the incurrence of significant

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capital expenditures for air pollution control equipment to limit or prevent releases of pollutants from our facilities, the expenditure of significant monies in the application of specific health and safety criteria addressing worker protection, the requirement to maintain information about hazardous materials used or produced in our operations and to provide this information to required parties, and the incurrence of significant costs and liabilities for pollution resulting from our operations or from those of prior owners or operators of our facilities. Numerous federal and state governmental authorities, such as the U.S. EPA, OSHA, the Louisiana Department of Environmental Quality (“LDEQ”), and the Montana Department of Environmental Quality (“MDEQ”), have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring challenging and costly actions. From time to time, we receive notices of violation, other enforcement proceedings and regulatory inquiries from governmental agencies alleging non-compliance with applicable environmental and occupational health and safety laws and regulations. Failure to comply with such laws and regulations as well as any issued permits and orders may result in the assessment of administrative, civil, and criminal sanctions, including monetary penalties, the imposition of remedial or corrective action obligations or the incurrence of capital expenditures, the occurrence of delays or cancellations in the permitting, development or expansion of projects, litigation, and the issuance of injunctions limiting or preventing some or all of our operations.

New worker safety and environmental laws and regulations, revised interpretations of such existing laws and regulations, increased governmental enforcement or other developments could require us to make additional, unforeseen expenditures. The adoption of more stringent environmental laws or regulations could impact us by requiring installation of new emission controls on some of our equipment, resulting in longer permitting timelines, and significantly increasing our capital expenditures and operating costs, which could adversely impact our business, cash flows and results of operation. Read Items 1 and 2 “Business and Properties — Environmental and Occupational Health and Safety Matters” for additional information.

Under the RFS provisions of the Clean Air Act, the EPA sets or adjusts volume mandates for the percentages of four compliance categories—cellulosic biofuel, biomass-based diesel, advanced biofuel, and total renewable fuel—to be blended into gasoline and diesel produced or imported during each calendar year. The EPA established these volume mandates for RFS program years 2023, 2024 and 2025 under final rules published in June 2023; the EPA further proposed RFS volume requirements for 2026 and 2027 in June 2025. We, and other refiners subject to RFS requirements, may meet those requirements by blending the necessary volumes of renewable transportation fuels into our production. To the extent that refiners cannot blend renewable fuels in the quantities required, those refiners may purchase renewable credits, referred to as RINs, which are created by blending done by others.

Our Shreveport and Great Falls refineries produce transportation fuels subject to the RFS volume mandates. Our annual RINs Obligation, which includes RINs that are required to be secured through either our own blending or through the purchase of RINs in the open market, is approximately 65 million RINs across the four compliance categories. However, the EPA granted certain of our refineries the small refinery exemption (“SRE”) provided by the RFS in past years including, most recently, in August 2025 for program years 2019 through 2024. Refineries that receive a SRE are not subject to the RFS renewable blending requirements for the exempt volume in the corresponding calendar year. We have submitted SRE petitions for our Shreveport and Great Falls refineries which are pending for 2025. Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for additional information relating to the status of SRE petitions for specific compliance years.

We cannot predict the final outcome of these matters or whether they may result in increased RFS program compliance costs. Moreover, the price of RINs remains subject to extreme volatility, with the potential for significant increases in price driven by political decisions rather than fundamentals. There also continues to be a shortage of advanced biofuel production resulting in increased difficulties meeting the original RFS program mandates. Our refineries produce a higher ratio of diesel than national averages, and since ethanol cannot be blended into diesel we therefore have a more difficult “compliance pathway” than average. The inability to receive an exemption under the RFS program for one or more of our refineries; any increase in the final minimum volumes of renewable fuels that must be blended with refined petroleum

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fuels; and/or any increase in the cost to acquire RINs may, individually or in the aggregate, have the potential to result in higher costs in connection with RIN compliance, which could be material.

Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information. Our involvement in such litigation may strain our resources, increase our costs and distract management, even if we are successful at certain stages. As long as the final outcome of our SRE petitions remains uncertain, we expect to carry a RINs liability on our consolidated balance sheets and any changes to such liability will be recognized as a charge or credit to net income (loss). As a result of such charges, investors may have a negative outlook on our financial position regardless of the actual impact these charges have on our business.

Our and our customers’ operations are subject to risks arising out of the threat of climate change, including regulatory, political, litigation and financial risks, which could result in increased operating and capital costs for our customers and reduced demand for the products and services we provide.

The threat of climate change continues to attract considerable attention in the United States and foreign countries. As a result, numerous approaches have been taken by international, national, regional and state regulatory bodies to monitor and limit emissions of GHGs as well as to eliminate such future emissions. As a result, our operations and potentially the operations of our customers are subject to a series of regulatory, political, physical, litigation and financial risks associated with the production and processing of fossil fuels and emissions of GHGs. See Items 1 and 2 “Business and Properties — Environmental and Occupational Health and Safety Matters” for more discussion on the threat of climate change and restriction of GHG emissions.

The adoption and implementation of any international, federal, regional or state executive actions, legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions or put a price on GHG emissions could result in increased compliance costs, additional operating restrictions or reduced demand for some of our services and products. Additionally, regulators in Europe and the U.S. have also focused efforts on increased disclosure related to climate change and mitigation efforts, which may significantly increase compliance burdens and associated regulatory costs and complexity. Further, increasing concentrations of GHGs in the Earth’s atmosphere may produce climatic changes that have significant physical effects, such as increased frequency and severity of storms, floods, wildfires and other climatic events. If any such effects were to occur, they could have an adverse effect on our operations or the operations of our suppliers and customers and result in more frequent and severe disruptions to our business and those of our suppliers and customers, increased costs to repair damaged facilities or maintain or resume operations, and increased insurance costs. Increasing attention to the risks of climate change has also resulted in an increased possibility of lawsuits or investigations brought by public and private entities against companies in the oil and natural gas sector in connection with their greenhouse gas emissions. While we do not produce oil or natural gas, if we were to be targeted by any such litigation or investigations, we may incur liability, which, to the extent that societal pressures or political or other factors are involved, could be imposed without regard to the causation of or contributions to the asserted damage, or to mitigating factors.

There are also increasing financial risks if stockholders and bondholders concerned about the potential effects of climate change may elect in the future to shift some or all of their investments into non-fossil fuel energy related sectors. Additionally, at times, the lending and investment practices of institutional lenders have been the subject of intensive lobbying efforts in recent years pressuring such lenders to not to provide funding for oil and natural gas producers. While we do not produce oil or natural gas, such developments could affect our cost and access to capital. Similarly, political, physical, financial and litigation risks may result in certain companies engaged in the oil and natural gas production business restricting, delaying or canceling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing the ability to continue to operate in an economic manner, which also could reduce demand for our products and services.

The occurrence of one or more of these developments could have a material adverse effect on our business, financial condition, results of operations and cash flows. Moreover, the increased competitiveness of alternative energy sources (such as wind, solar, geothermal and tidal), as well as any regulatory or other incentives to conserve energy, could reduce demand for hydrocarbons and therefore for our products, which could lead to a reduction in our revenues and cash flow

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available for payments on our debt obligations. For example, the Inflation Reduction Act of 2022 contained tax inducements and other provisions that incentivize investment, development, and deployment of alternative energy sources and technologies, but many of these tax inducements have been rescinded by the current administration and/or The One Big Beautiful Bill Act (“OBBBA”).

Our operations require numerous permits and authorizations under various occupational, environmental, import/export, and other laws and regulations. These authorizations and permits are subject to revocation, renewal or modification and can require operational changes to limit impacts or potential impacts on the environment and/or the health or safety of workers. Changes in leadership or priorities at the federal or state level may result in more stringent conditions with respect to the acquisition of these authorizations and permits. Additionally, a violation of an authorization or permit conditions or other legal or regulatory requirements could result in substantial fines, criminal sanctions, permit revocations, injunctions and/or facility shutdowns. Any or all of these matters could have a negative effect on our business, results of operations and cash flow available for payments on our debt obligations.

Our business involves the transportation by rail of crude oil, which involves risks of derailment, accidents and liabilities associated with cleanup and damages, as well as regulatory changes that may adversely impact our business, financial condition or results of operations.

Our operations involve the transportation of crude oil by rail on railcars that we lease. Past derailments of trains transporting crude oil in the U.S. and Canada have caused various regulatory agencies and industry organizations, as well as federal, state and municipal governments, to focus attention on transportation of flammable materials by rail. We cannot assure you that costs incurred to comply with any new standards and regulations will not be material to our business, financial condition or results of operations. In addition, any derailment involving crude oil that we have purchased or are shipping may result in claims being brought against us that may involve significant liabilities. Although we believe that we are adequately insured against such events, we cannot provide assurance that our policies will cover the entirety of any damages that may arise from such an event.

Subsidiaries

We have a holding company structure in which our subsidiaries conduct our operations and own our operating assets and our ability to make payments of our debt obligations depends on the performance of our subsidiaries and their ability to distribute funds to us.

We are a holding company, and our subsidiaries conduct all of our operations and own all of our operating assets. We have no significant assets other than the equity interests in our subsidiaries. As a result, our ability to make payments of debt obligations depends on the performance of our subsidiaries and their ability to distribute funds to us. The ability of our subsidiaries to make distributions to us is restricted by our revolving credit facility and the indentures governing our senior notes and may be restricted by, among other things, applicable state laws and other laws and regulations. If we are unable to obtain the funds necessary to make payments of debt obligations, we may be required to adopt one or more alternatives, such as a refinancing our indebtedness or incurring borrowings under our revolving credit facility. We cannot assure stockholders that we would be able to refinance our indebtedness or that the terms on which we could refinance our indebtedness would be favorable.

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Risks Related to Montana Renewables

If there is not sufficient demand for renewable energy, if renewable energy markets do not develop or take longer to develop than we anticipate, or if we do not realize the expected SAF premium, we may be unable to achieve our investment objectives for MRL, which could have a material adverse impact on our results of operations and financial condition.

If demand for renewable energy fails to grow sufficiently, we may be unable to achieve our business objectives for MRL. Many factors will influence the widespread adoption of renewable energy and demand for renewable energy projects, including:

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cost-effectiveness of renewable energy technologies as compared with conventional and competitive technologies;

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performance and reliability of renewable energy products as compared with conventional and non-renewable products;

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fluctuations in economic and market conditions that impact the viability of conventional and competitive alternative energy sources;

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increases or decreases in the prices of oil, coal and natural gas; and

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availability or effectiveness of government subsidies, incentives and mandates.

We also face the risks that SAF cannot generate the premium we currently expect, that a market for SAF does not evolve as expected and that alternate technologies supersede the expected demand for SAF. Any of these factors may preclude us from achieving our investment objectives for MRL and, by extension, could have a material adverse impact on our results of operations and financial condition.

Montana Renewables is subject to numerous operating risks, which could materially adversely impact our results of operations and financial conditions.

Montana Renewables was formed in 2021 and has a limited operating history, distributing renewable fuels since December 2022. The Company is experienced in operating facilities, such as the Montana Renewables facility, and expects to continue to leverage the Company’s operating experience, as well as its experience in selling and distributing renewable fuels.

As with any facilities of similar size and nature, the operations of Montana Renewables could be affected by many factors, including start-up problems, the breakdown or failure of equipment or processes, the performance of Montana Renewables below expected levels of output or efficiency, renewable feedstock or utility supply disruptions, rail service disruptions, environmental proceedings or other litigation that compel cessation of all or a portion of the operations, cyber-security considerations, increased stringent environmental operating, storage and transportation regulations, and/or, labor disputes. Additionally, the operations of Montana Renewables could be affected by both natural or man-made catastrophic events beyond our control, such as fires, earthquakes, floods, severe storms, extreme temperatures, explosions, major accidents, armed conflict, hostilities, acts of terrorism, health emergencies, cyber and physical attacks and/or similar events.

The occurrence of such events could significantly reduce or eliminate revenues generated by Montana Renewables and significantly increase the expenses of Montana Renewables, thereby jeopardizing the ability of Montana Renewables to generate revenues sufficient to pay its outstanding debt obligations. While the Company maintains insurance to protect against certain of these operating risks, the proceeds of such insurance may not be adequate to cover Montana Renewable’s lost revenues or increased costs. Under such circumstances, no assurance can be given concerning the ability of Montana Renewables to generate sufficient revenues to make timely payments of its debt obligations.

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Montana Renewables Holdings LLC (“MRHL”) may also face civil liabilities or fines in the ordinary course of its business as a result of damages to third parties. These liabilities may result in the MRHL making indemnification payments in accordance with applicable laws to the extent and in the amount that such indemnification payments are not covered by the Company’s insurance policies.

During the start-up of operations or expansion of operations, new facilities like Montana Renewables could be susceptible to operational failures which may result in temporary maintenance shutdowns. Although the initial commissioning of the facility was successful, any significant curtailing of production at Montana Renewables may result in materially lower levels of revenues or cash flows and materially increased expenses for the duration of any downtime and may materially adversely impact our results of operations, financial conditions and ability to pay the principal of, redemption premium, if any, and/or interest on outstanding debt obligations.

Montana Renewables is subject to a number of statutes and regulations that could have an adverse effect on Montana Renewables’ operations.

We are required to comply with a number of statutes and regulations relating to the environment and the safety and health of our employees and the public during the operation of our Montana Renewables facility, such as: limits on noise emissions from the Montana Renewables facility; safety and health standards, practices and procedures applicable to the operation of the Montana Renewables facility; environmental protection requirements, including standards and limits relating to the discharge of pollutants and waste to the air, water and land; and employment, hiring and anti-discrimination requirements relating to the operation of the Montana Renewables facility.

Federal, state, and local laws and regulations protecting the environment require us to obtain permits and other authorizations to operate the Montana Renewables facility. Changes in such laws could materially and adversely affect our costs. Permits that have been obtained or will be obtained may be subject to challenge in public proceedings, including the filing of administrative or judicial appeals contesting the validity or the terms of the permits. If such permits are challenged, the operation of the Montana Renewables facility may be delayed or prohibited, and elements of our Montana Renewables facility may need to be removed, redesigned or replaced.

All permits and approvals issued by governmental agencies expire and must be renewed if the permitted activity is not complete. Renewals of operating permits require ongoing compliance and may result in new requirements being imposed by governmental agencies. There is no assurance that required renewals will be obtained when required to continue operation or that the Montana Renewables facility will be able to satisfy the requirements for renewal or continued operation. The inability to maintain required permits in force and effect, and their amendment, suspension or revocation would have adverse effects on the Montana Renewables facility’s operations and our financial performance. Additionally, as a result of the DOE Loan, Montana Renewables is subject to various covenants and compliance requirements, such as paying prevailing wages and complying with the Davis-Bacon Act of 1931. These additional requirements could result in increased compliance costs and any failure to comply with these requirements could have a material adverse effect on the Company.

A significant component of our product margin consists of a variety of government subsidies, incentives and mandates, and any changes in law that eliminate or reduce these subsidies, incentives and mandates would have a material adverse impact on our results of operations and financial condition.

As with many producers, our margins are supported by federal, state and provincial government programs that incentivize the production, blending and use of renewable and low-carbon fuels. While the general trend over time has been for these programs to expand both in number and scope, such continued growth is not guaranteed and is subject to potential changes in political and public support. For example, since the enactment of the U.S. blender’s tax credit (“BTC”) (Section 40A of the IRC) in 2004 with specified sunset dates, there have been several occasions where the renewal and extension of the credit has been in doubt, only for it to be renewed and extended close to (and in some cases, after) expiration. Many factors affect political and public support, which cannot be fully evaluated or predicted at this time.

In addition, programs that enjoy political and public support may nonetheless evolve over time in ways that may limit opportunities for our renewable transportation fuel. For example, in September 2020, California Governor Gavin Newsom

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issued Executive Order N-79-20, establishing goals of 100% of new passenger vehicle sales in-state to be zero-emission by 2035, and all heavy-duty truck sales to be zero-emission by 2045. The order further directs the California Air Resources Board to develop regulations to achieve these goals. While the precise nature of future regulations cannot be predicted, it is possible that incentives for renewable fuel products may be scaled back or more stringent emission reduction standards may be adopted to facilitate the transition to zero-emission vehicles. These and similar initiatives reflect an ever evolving legal and regulatory landscape, which introduces uncertainty in evaluating future governmental support for our products.

Certain regulatory programs feature a periodic update process. The U.S. Renewable Fuel Standard program, for example, has historically required EPA to set RVOs each year, in light of volumes of four categories of renewable fuels established by Congress in the Clean Air Act. More recently, EPA promulgated regulations setting RVOs for a three-year period (2023, 2024 and 2025). The periodic update process featured in the RFS and similar programs nonetheless introduces a degree of uncertainty in demand for our products on a yearly basis.

Transactions between the Company and MRL present possible conflicts of interest that could have an adverse effect on the Company if they are not managed appropriately.

MRHL has no assets other than its equity interests in MRL. Several of the Company’s affiliates have been or are expected to be involved with the operation of Montana Renewables, including the sales and marketing of the renewable fuels produced by Montana Renewables. The support and experience of the Company’s affiliates are expected to be important to the success of Montana Renewables. However, no affiliates of the Company are obligated to make any payments with respect to outstanding debt obligations of MRHL or MRL and any such transactions between the Company and MRHL or MRL present possible conflicts of interest that could have an adverse effect on the Company if they are not managed appropriately.

Montana Renewables depends on the Company to provide MRL with services necessary to operate its business. If the Company were unable or unwilling to provide these services, it would result in a disruption in MRL’s business that could have an adverse effect on its financial position, financial results and cash flow.

MRL does not directly employ directors, officers or employees. Pursuant to the master services agreement (the “MSA”) with a wholly-owned subsidiary of the Company, all of MRL’s executive management personnel are employees of the Company, and MRL uses a significant number of the Company’s employees to operate the Montana Renewables facility and provide MRL with general and administrative services as well as services related to information technology, cybersecurity and data privacy. The failure of the Company to provide accurate and timely service may adversely impact MRL’s business operations. In addition, if the Company were to become unable or unwilling to provide such services, MRL would need to develop these services internally or arrange for the services from another service provider, which may not be possible and which could take time and cause MRL to experience significant interruptions or incur additional costs. Developing the capabilities internally or by retaining another service provider could have an adverse effect on MRL’s business, and the services, when developed or retained, may not be of the same quality as provided to us by the Company. For example, if MRL is not able to obtain adequate information technology and cybersecurity services, MRL may be at a higher risk for cyberattacks and other interruptions or failures. Additionally, if the MSA were to terminate, MRL would lose its key personnel.

We rely on railroad and trucking companies to transport renewable feedstock materials to the Montana Renewables facility, and to deliver renewable transportation fuels to our customers. These transportation services are subject to various hazards, including extreme weather conditions, floods, droughts, work stoppages, delays, accidents such as spills and derailments and other accidents and other operating hazards. Increasing climate risk may exacerbate weather conditions so as to materially affect the economics of traditional transportation methods. These transportation operations, equipment and services are also subject to environmental, safety, and regulatory oversight. Due to concerns related to accidents, local and national governments could implement new regulations affecting the transportation of our renewable feedstock materials or renewable transportation fuels. We may be unable to ship the renewable transportation fuels or obtain renewable feedstock materials as a result of these transportation companies’ failure to operate properly, or if new and more

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stringent regulatory requirements are implemented affecting transportation operations or equipment. If there are significant increases in the cost of such transportation services or equipment, or changes in such costs relative to transportation costs incurred by competitors, our sales revenues and/or cost of operations could be materially and adversely affected.

Montana Renewable’s operations are dependent on the use of intellectual property licensed to MRL by third parties, and if MRL fails to comply with our obligations under such license agreements, we may be required to pay damages, and we could lose license rights that are critical to our business.

Montana Renewable’s operations are dependent upon the use of intellectual property licensed to us by third parties, and in the future, MRL may enter into additional agreements for certain other intellectual property or technologies. If MRL fails to comply with terms of its license agreements related to such intellectual property or other technologies, the applicable licensor may have the right to terminate its license or MRL may be required to pay damages. Termination by the licensor may cause MRL to lose valuable rights and could prevent MRL from operating the Montana Renewables facility or otherwise operating its business. Our business may suffer if any current or future licenses terminate, if the licensors fail to abide by the terms of the license, if the licensors fail to enforce licensed patents against infringing third parties, if the licensed intellectual property rights are found to be invalid or unenforceable, or if we are unable to enter into necessary licenses on acceptable terms. In addition, our rights to the licensed intellectual property are licensed to us on a non-exclusive basis. The owners of these non-exclusively licensed technologies are therefore free to license them to third parties, including our competitors, on terms that may be superior to those offered to us, which could place us at a competitive disadvantage. Moreover, our licensors may own or control intellectual property that has not been licensed to us and, as a result, we may be subject to claims, regardless of their merit, that we are infringing, misappropriating or otherwise violating the licensor’s rights. In addition, the agreements under which we license intellectual property or technology from third parties are generally complex, and certain provisions in such agreements may be susceptible to multiple interpretations. The resolution of any contract interpretation disagreement that may arise could narrow what we believe to be the scope of our rights to the relevant licensed intellectual property or technology or increase what we believe to be our financial or other obligations under the relevant agreement. Failure to obtain, maintain or renew these licenses, along with any of the foregoing, could have a material adverse effect on our ability to operate the Montana Renewables facility.

The production of renewable fuels is a growing industry, and we are expecting to encounter significant competition in the marketplace.

The production of renewable fuels is a growing industry, and we are expecting to encounter significant competition in the marketplace. Emerging trends that develop as industry production of renewable fuels increases may adversely affect our business, financial condition, results of operations and prospects. We have encountered and will continue to encounter risks and difficulties frequently experienced by growing companies in rapidly changing industries, including unpredictable and volatile revenues and increased expenses as our business continues to grow. In addition, new technologies or methods of operation may be developed that improve the quality of the fuel, increase production, or decrease the costs of production.

Montana Renewables balance sheet includes a Loan Guarantee Agreement (the “LGA”) with the U.S. Government.

On January 10, 2025, Montana Renewable and the U.S. Department of Energy entered into a Loan Guarantee Agreement whereby Montana Renewables may borrow from the Federal Finance Bank of the U.S. Treasury, and DOE will guarantee repayment of that indebtedness (the “DOE Loan”). Calumet is not a guarantor. On January 28, 2025 MRL drew a first advance of approximately $782 million at a 15-year tenor and an interest rate of 4.884%. The LGA gives DOE the right to approve certain activities which may limit MRL freedom of action or conflict with stockholder interests. Should MRL default under the LGA the repayment of MRL indebtedness would be accelerated.

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Risk Related to our Material Weakness

We have remediated the material weaknesses previously reported in our internal control over financial reporting, but if we identify additional material weaknesses in the future or fail to maintain an effective system of internal control we may not be able to accurately and timely report our financial results, which may affect investor confidence and cause us to incur additional costs resulting in adverse impacts to our results of operations.

As a public company, we are required to establish and periodically evaluate procedures with respect to our disclosure controls and procedures and our internal control over financial reporting. In the course of preparing our unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2025, we identified an error in the Company’s historical unaudited condensed consolidated statements of cash flows for the periods ended March 31, 2025 and June 30, 2025 that caused a misclassification of certain amounts between cash flow from operating activities and cash flows from financing activities. A material weakness is a deficiency, or combination of deficiencies, in our internal control over financial reporting such that there is a reasonable possibility that a material misstatement of our annual or interim consolidated financial statements would not be prevented or detected on a timely basis. After completing several remedial actions as described in Part II, Item 9A “Controls and Procedures” we have remediated the previously identified material weaknesses as of December 31, 2025.

However, there can be no assurance that the measures we have taken to date, or any actions we may take in the future, will be effective in preventing or mitigating potential future material weaknesses. Our current controls and any new controls that we develop may become inadequate because of changes in conditions in our business. Further, additional weaknesses in our disclosure controls and procedures and internal control over financial reporting may be discovered in the future. If we are then unable to remediate the material weaknesses in a timely manner and further implement and maintain effective internal control over financial reporting or disclosure controls and procedures, our ability to record, process, and report financial information accurately, and to prepare financial statements within required time periods could be adversely affected, which could result in material misstatements in our financial statements that may continue undetected or a restatement of our financial statements for prior periods. This may negatively impact the public perception of the Company and cause investors to lose confidence in the accuracy and completeness of our financial reports, harm our ability to raise capital on favorable terms, or at all, in the future, and subject us to litigation or investigations by regulatory authorities, which could require additional financial and management resources or otherwise have a negative impact on our financial condition.

In addition, we have incurred and expect to continue to incur significant expenses and devote substantial management effort toward our efforts to achieve and maintain effective internal control over financial reporting. As a result of the complexity involved in complying with the rules and regulations applicable to public companies, our management’s attention may be diverted from other business concerns, which could harm our business, operating results, and financial condition. Although we have already implemented various actions to remediate the material weakness, we may find in the future that we do not have adequate systems, processes or personnel with the appropriate level of knowledge over financial reporting required of public companies and may need to take additional remediation steps in the future, or engage outside consultants, which will increase our operating expenses.

We reached a determination to restate certain of our previously issued unaudited condensed consolidated financial statements, which may affect investor confidence.

We previously reached a determination to restate our unaudited consolidated financial statements and related disclosures for the quarters ended March 31, 2025 and June 30, 2025, following the identification of an error in the unaudited condensed consolidated statements of cash flows as a result of the misclassification of certain amounts between cash flows from operating activities and cash flows from financing activities. As a result, we have become subject to a number of additional risks and uncertainties, which may affect investor confidence in the accuracy of our financial disclosures

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Risks Related to Our Common Stock

The price of our common stock may experience volatility.

The price of our common stock may be volatile. In addition to the risk factors described above, some of the factors that could affect the price of our common stock are quarterly increases or decreases in revenue or earnings, changes in revenue or earnings estimates by the investment community, sales of our common stock by significant stockholders, short-selling of our common stock by investors, issuance of a significant number of shares to raise additional capital to fund our operations, changes in market valuations of similar companies and speculation in the press or investment community about our financial condition or results of operations. General market conditions and U.S. or international economic factors and political events unrelated to the performance of us may also affect our stock price. For these reasons, investors should not rely on recent trends in the price of our common stock to predict the future price of our common stock or our future financial results.

Our amended and restated certificate of incorporation and amended and restated bylaws contain provisions that may make it more difficult for a third party to acquire control of us, even if a change in control would result in the purchase of your shares of common stock at a premium to the market price or would otherwise be beneficial to you.

There are provisions in our amended and restated certificate of incorporation and amended and restated bylaws that may make it more difficult for a third party to acquire control of us, even if a change in control would result in the purchase of your shares of common stock at a premium to the market price or would otherwise be beneficial to you. For example, our amended and restated certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us.

In addition, provisions of our amended and restated certificate of incorporation and amended and restated bylaws, including a classified board of directors, so that only approximately one-third of our directors are elected each year, and limitations on stockholder actions by written consent and on stockholder proposals and director nominations at meetings of stockholders, could make it more difficult for a third party to acquire control of us. Certain provisions of the Delaware General Corporation Law (“DGCL”) may also discourage takeover attempts that have not been approved by our board of directors.

Our amended and restated certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, and the federal district courts as the exclusive forum for Securities Act claims, which could limit stockholders’ ability to obtain what such stockholders believe to be a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

Our amended and restated certificate of incorporation provides that, unless we select or consent in writing to the selection of an alternative forum, all complaints asserting any internal corporate claims (defined as claims, including claims in the right of the Company: (i) that are based upon a violation of a duty by a current or former director, officer, employee or stockholder in such capacity; or (ii) as to which the DGCL confers jurisdiction upon the Court of Chancery), to the fullest extent permitted by applicable law, and subject to applicable jurisdictional requirements, shall be the Court of Chancery of the State of Delaware (or, if the Court of Chancery does not have, or declines to accept, jurisdiction, another state court or a federal court located within the State of Delaware). Further, unless we select or consent to the selection of an alternative forum, the federal district courts of the United States will be the exclusive forum for the resolution of any complaint asserting a cause of action arising under the Securities Act. Our choice of forum provision does not apply to suits brought to enforce any liability or duty created by the Exchange Act and investors cannot waive compliance with the federal securities laws and the rules and regulations thereunder. Any person or entity purchasing or otherwise acquiring any interest in shares of our common stock will be deemed to have notice of, and consented to, the provisions of our amended and restated certificate of incorporation described in the preceding sentence. This choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our amended and restated certificate of incorporation inapplicable to, or unenforceable in

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respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition or results of operations.

We do not expect to pay dividends on our common stock for the foreseeable future.

We do not expect to pay dividends for the foreseeable future. In addition, our revolving credit facility may prohibit us from paying any dividends without the consent of the lenders under our revolving credit facility.

We cannot predict the effect of future sales of shares or the availability of shares for future sales, on the market price of or the liquidity of the market for the shares of our common stock. Sales of substantial amounts of shares of our common stock, or the perception that such sales could occur, could adversely affect the prevailing market price of the shares of our common stock. Such sales, or the possibility of such sales, could also make it difficult for us to sell equity securities in the future at a time and at a price that we deem appropriate.

Our authorized capital stock consists of 700,000,000 shares of common stock and 100,000,000 shares of preferred stock, a significant portion of which is unissued. We may need to raise a significant amount of capital to pay down outstanding indebtedness, including principal, interest and fees due under our revolving credit facility, the senior notes, the DOE Facility and our other indebtedness and may raise such capital through the issuance of newly issued common stock or preferred stock. Additionally, outstanding warrants to purchase an aggregate of 2,000,000 shares of common stock are exercisable through July 10, 2027. Such issuance and sale of equity could be dilutive to the interests of existing stockholders and increase the number of shares eligible for resale in the public market.

Additionally, as of February 26, 2026, The Heritage Group and certain of their affiliates beneficially owned approximately 19.4% of the outstanding shares of our common stock (prior to any potential dilution resulting from exercise of the warrants). The Sponsor Parties have registration rights with respect to the shares of common stock they receive pursuant to the Conversion. Pursuant to the Registration Rights Agreement, we have filed a shelf registration statement with respect to the registrable securities under the Registration Rights Agreement. No more than two times in any 12-month period, the Sponsor Parties may request to sell all or any portion of their registrable securities in an underwritten offering so long as the total offering price is reasonably expected to exceed $25 million. We also agreed to provide customary “piggyback” registration rights to the Sponsor Parties. The Registration Rights Agreement also provides that we will pay certain expenses relating to such registrations and indemnify the stockholders against certain liabilities. The Sponsor Parties’ shares of common stock is currently eligible for sale into the market without volume limitations. Because of the substantial size of the Sponsor Parties’ holdings, the sale of a significant portion of these shares, or a perception in the market that such a sale is likely, could have a significant impact on the market price of such shares.

Risks Related to Tax Matters

Compliance with and changes in tax laws could adversely affect our performance.

The Company is subject to extensive tax liabilities, including federal, state, local and foreign taxes such as income, excise, sales/use, payroll, franchise, property, gross receipts, withholding and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations, such as OBBBA, are continuously being enacted or proposed and could result in increased expenditures for tax liabilities in the future. These liabilities are subject to periodic audits by the respective taxing authorities, which could increase our tax liabilities. Subsequent changes to our tax liabilities as a result of these audits may also subject us to interest and penalties. There can be no certainty that our federal, state, local or foreign taxes could be passed on to our customers.

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We are currently unable to fully utilize the CFPCs that we generate, and as such, we are exposed to fluctuations in the market prices of CFPCs and the potential unavailability of third parties willing to purchase CFPCs.

The CFPCs that we generate can be realized by applying them to the Company’s federal income tax liability or selling CFPCs in the secondary market at a discounted rate. We are currently unable to fully utilize the CFPCs that we generate. For example, we generated $102.5 million of CFPCs during the year ended December 31, 2025 and we currently intend to sell all of such CFPCs in the secondary market. As a result, we are exposed to fluctuations in the market prices of CFPCs and the potential unavailability of third parties willing to purchase CFPCs. If the prevailing market prices of CFPCs decline or if we are unable to sell our available CFPCs in a timely manner or at all, we may realize significantly less than the notional value of the CFPCs that we generate, which could have a material adverse effect on our business, financial condition and results of operations.

Item 1B. Unresolved Staff Comments

None.

Item 1C. Cybersecurity

We maintain a cyber risk management program designed to identify, assess, manage, mitigate, and respond to cybersecurity threats. An analysis of the impact, likelihood, and management preparedness of cybersecurity threats to our strategic priorities is integrated into our enterprise risk management program and enterprise risk assessment process. This is intended to provide cross-functional visibility, as well as executive leadership oversight, to address and mitigate associated risks. Our internal IT group audits our information security programs, and the results are reported to our executive management and the Risk Committee of our Board of Directors by the Vice President of Information Technology. We also engage third-party firms to identify, assess, and manage cybersecurity risks in alignment with cybersecurity standards. We further employ systems and processes designed to oversee, identify, and reduce the potential impact of a cybersecurity incident at a third-party vendor, service provider or customer or otherwise implicating the third-party technology and systems we use. We also carry cybersecurity insurance to protect against potential losses arising from a cybersecurity incident. Our policies and procedures also address the oversight, identification, and mitigation of cybersecurity risks associated with our use of third-party service providers.

We have an Incident Response Plan (“IRP”) that defines and documents procedures for assessing, identifying, and managing a cybersecurity incident. The IRP sets out a coordinated approach to investigating, containing, documenting and mitigating incidents, including reporting findings and keeping senior management and other key stakeholders informed and involved as appropriate. In general, our incident response process aligns with the NIST framework and focuses on four phases: preparation; detection and analysis; containment, eradication and recovery; and post-incident remediation. The IRP applies to all personnel (including third-party partners) that perform functions or services require access to secure Company information, and to all devices and network services that are owned or managed by the Company. We also have protocols by which certain cybersecurity incidents are escalated within the Company and, where appropriate, reported to the Board of Directors.

Our Vice President of Information Technology, who has extensive cybersecurity knowledge and skills gained from over twenty years of work experience at the Company and elsewhere, heads the team responsible for implementing, monitoring and maintaining cybersecurity and data protection practices across our business and reports directly to the Executive Vice President — Chief Financial Officer. The Vice President of Information Technology receives reports on cybersecurity threats from a number of experienced information security officers responsible for various parts of the business on an ongoing basis and in conjunction with management, regularly reviews risk management measures implements by the Company to identify and mitigate data protection and cybersecurity risks. Our Vice President of Information Technology works with Legal to oversee compliance with legal, regulatory, and contractual security requirements. In addition, the Company routinely provides various types of cybersecurity trainings to its employees.

Our Board has delegated the primary responsibility to oversee cybersecurity matters to the Risk Committee. Aside from more immediate reporting of certain incidents to our Board of Directors as described above, our Vice President of Information Technology provides our Risk Committee an update on cybersecurity at least every other quarter and more

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often as necessary. This update includes metrics on the effectiveness of technical and human security controls, cybersecurity training program compliance, internal and third-party cybersecurity incidents, and cybersecurity risks.

Risks from cybersecurity threats, including as a result of any previous cybersecurity incidents, have not materially affected us, including our business strategy, results of operations or financial condition. If our systems, or our customers' or suppliers' systems, for protecting against cybersecurity incidents prove to be insufficient, a cybersecurity incident could have a material adverse effect on our business, operations, or consolidated financial condition. As part of our overall risk mitigation strategy, the Company maintains cyber insurance coverage; however, such insurance may not be sufficient in type or amount to cover us against claims related to cybersecurity incidents or other related breaches. Refer to Part I, Item 1A “Risk Factors — Risks Related to Our Business” for additional information about our cybersecurity risks.

Item 3. Legal Proceedings

We are not a party to, and our property is not the subject of, any pending legal proceedings other than ordinary routine litigation incidental to our business. Our operations are subject to a variety of risks and disputes normally incident to our business. As a result, we may, at any given time, be a defendant in various legal proceedings and litigation arising in the ordinary course of business. Read Items 1 and 2 “Business and Properties — Environmental and Occupational Health and Safety Matters” for a description of our current regulatory matters related to the environment, health and safety. Additionally, the information provided under Note 6 — “Commitments and Contingencies” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” is incorporated herein by reference.

Item 4. Mine Safety Disclosures

Not applicable.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Market Information

Our common stock is quoted and traded on the Nasdaq Global Select Market (“Nasdaq”) under the symbol “CLMT.” As of February 27, 2026, there were approximately 17 registered holders of record of our common stock. A substantially greater number of holders of our common stock are “street name” or beneficial holders, whose shares of record are held by banks, brokers and other financial institutions. As of February 27, 2026, there were 86,776,552 shares of our common stock outstanding.

We do not expect to pay dividends for the foreseeable future. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our results of operations, financial condition, capital requirements, investment opportunities, and restrictions under our debt agreements.

Sales of Unregistered Securities

None.

Issuer Purchases of Equity Securities

None.

Item 6. Reserved

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The historical consolidated financial statements included in this Annual Report reflect all of the assets, liabilities and results of operations of Calumet, Inc. and its consolidated subsidiaries (“Calumet,” the “Company,” “we,” “our,” or “us”). The following discussion analyzes the financial condition and results of operations of the Company for the years ended December 31, 2025, 2024, and 2023, respectively. Stockholders should read the following discussion and analysis of the financial condition and results of operations of the Company in conjunction with the historical consolidated financial statements and notes included elsewhere in this Annual Report.

Overview

Our operations are managed using the following reportable segments: Specialty Products and Solutions; Performance Brands; Montana/Renewables; and Corporate. For additional information, refer to Note 18 — “Segments and Related Information” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements.” In our Specialty Products and Solutions segment, we manufacture and market a wide variety of solvents, waxes, customized lubricating oils, white oils, petrolatums, gels, esters, and other products. Our specialty products are sold to domestic and international customers who purchase them primarily as raw material components for consumer-facing and industrial products. In our Performance Brands segment, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our Montana/Renewables segment is comprised of two facilities — renewable fuels and specialty asphalt. At our Montana renewable fuels facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel, and renewable naphtha that are distributed into renewable markets in the western half of North America. At our Montana specialty asphalt facility, we process Canadian crude oil into conventional gasoline, diesel, jet fuel and specialty grades of asphalt, with production sized to serve local markets. Our Corporate segment primarily consists of general and administrative expenses not allocated to the Specialty Products and Solutions, Performance Brands or Montana/Renewables segments.

Recent Developments

9.75% Senior Notes due 2031

On January 12, 2026, Calumet Specialty Products Partners, L.P. (the “Partnership”) and Calumet Finance Corp. (“Finance Corp.” and, together with the Partnership, the “Issuers”), each a subsidiary of the Company, issued $405.0 million aggregate principal amount of a new series of the Issuers’ 9.75% Senior Notes due 2031 (the “2031 Notes”) in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act of 1933, as amended (the “Securities Act”). The Company subsequently redeemed all of the Issuers’ outstanding 11.00% Senior Notes due 2026 (the “2026 Notes”) and all of the Issuers’ outstanding 8.125% Senior Notes due 2027 (the “2027 Notes”) on or before January 21, 2026. Refer to Note 21 — “Subsequent Events” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information.

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Ninth Amendment to Third Amended and Restated Credit Agreement

On January 23, 2026, the Company entered into the Ninth Amendment to the Third Amended and Restated Credit Agreement (the “Ninth Amendment”). The Ninth Amendment amended the Third Amended and Restated Credit Agreement, dated as of February 23, 2018 (the “Credit Agreement”), by and among Calumet GP, LLC, Calumet Specialty Products Partners, L.P., certain subsidiaries of the Company party thereto, the lenders party thereto and Bank of America, N.A., as administrative agent. Among other changes, the Ninth Amendment modified the Credit Agreement to (i) extend the maturity date to January 23, 2031, (ii) provide for commitments of $500.0 million, subject to borrowing base limitations, (iii) revise certain covenants, representations and warranties, events of default and other terms to permit the Company or one or more of its subsidiaries to consummate one or more new inventory financing transactions, subject in each case to the Company’s satisfaction of certain customary conditions and (iv) provide for a reduction of commitments under the Credit Agreement from $500.0 million to $425.0 million if any such inventory financing transaction is consummated. Refer to Note 21 — “Subsequent Events” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information.

Hedging Activities

During the fourth quarter of 2025, the Company entered into crack spread swaps for 10,000 barrels per day, which is approximately 25% of the Company’s expected fuels production. Refer to Note 9 — “Derivatives” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for additional information.

2025 Update

Outlook and Trends

During the fourth quarter of 2025, our business continued to benefit from strong and reliable operations. In the fourth quarter, we achieved an operational milestone, setting a new production record in our Specialty Products and Solutions segment. At Montana Renewables, we continue to meet or outperform our operational cost targets and demonstrate success in monetizing Section 45Z Clean Fuel Production Tax Credits (“CFPCs”). This enhanced operational performance is a direct result of the capital investments we have made over the past few years on projects designed to improve asset reliability.

In our Specialties Products and Solutions and Performance Brands segments, we continue to benefit from an attractive specialty product margin environment. Compared to the third quarter, our fuels and asphalt business benefitted from improved commodity margins. Demand for our products in these businesses remained strong in comparison to historical averages and we continue to leverage the benefits of our fully integrated specialty business in this market. We expect the current margin environment for both specialty products and fuel based products to continue into the first quarter of 2026.

In our Montana/Renewables segment, we maintain our outlook of strong demand for renewable fuel products. We believe long-term demand for renewable fuel products will continue to grow as a result of the increased Federal policy focus on domestic fuel production, expansion of both voluntary and mandatory corporate decarbonization targets, particularly the global aviation industry, strategic alignment with the agricultural industry as a source of renewable feedstocks, broad sustainability initiatives, and Federal, State, Provincial and local governmental mandates and incentives that have been passed or announced in North America and globally. In aviation, forecasted SAF availability falls short of the necessary emissions reductions that would be required to reach established decarbonization and/or net-zero goals, which will drive SAF pricing. We believe that our advantage as a first-mover in the renewable fuels market positions us as a key producer for potential offtake partners to help them reach their announced targets.

Our Montana specialty asphalt facility continued to be impacted by narrower than usual WCS-WTI spreads in the fourth quarter, but is beginning to experience marginal benefit from the widening of heavy crude oil spreads in response to recent market and geopolitical events. The facility remains strategically advantaged due to its local access to cost-advantaged Canadian conventional crude oil, while producing additional fuels and refined products for delivery into the regional market. Due to its strategic location and logistical capabilities, we believe that our Montana specialty asphalt facility is well-positioned to continue to serve long-standing customers in the regional market.

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As we have experienced in the past several years, our integrated business model and diversified product portfolio provides an advantaged response to changing market conditions. While we are not immune to the impacts of an economic downturn, we believe our specialty business is well positioned in periods of raw material volatility, which can negatively impact short-term margins, and a variety of economic conditions.

Contingencies

For a summary of litigation and other contingencies, read Note 6 — “Commitments and Contingencies” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements.” Based on information available to us at the present time, we do not believe that any liabilities beyond the amounts already accrued, which may result from these contingencies, will have a material adverse effect on our liquidity, financial condition or results of operations.

Financial Results

We reported a net loss of $33.8 million in 2025, versus net loss of $222.0 million in 2024. We reported Adjusted EBITDA with Tax Attributes (as defined in Item 7 “Management’s Discussion and Analysis — Non-GAAP Financial Measures”) of $293.3 million in 2025, versus $229.3 million in 2024. We generated cash from operating activities of $108.9 million in 2025, versus using cash from operating activities of $46.4 million in 2024.

Read Item 7 “Management’s Discussion and Analysis — Non-GAAP Financial Measures” for a reconciliation of EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes to Net income (loss), our most directly comparable financial performance measure calculated and presented in accordance with U.S. generally accepted accounting principles (“GAAP”).

Specialty Products and Solutions segment Adjusted EBITDA was $291.8 million in 2025 compared to $222.5 million in the prior year. The year-over-year increase was driven by stronger commodity margins and improved operational reliability across our integrated asset base. Enhanced reliability and throughput enabled greater margin capture and higher sales volumes, contributing meaningfully to the improvement in results.

Montana/Renewables segment Adjusted EBITDA was negative $50.8 million in 2025 compared to $22.3 million in 2024. Montana/Renewables segment Adjusted EBITDA with Tax Attributes was $31.3 million in 2025 compared to $22.3 million in 2024. Compared to the prior year, Montana/Renewables segment Adjusted EBITDA with Tax Attributes was favorably impacted by improved operational reliability, as well as significant reductions in our operating costs. In our renewable fuels business, margins continued to be depressed by the current Renewable Volume Obligation’s disconnection with industry supply of biomass-based diesel. In our legacy specialty asphalt business, improvements in margin contributed $5.0 million in additional year-over-year Adjusted EBITDA with Tax Attributes, but were constrained by a tighter than usual WCS-WTI spread.

Performance Brands segment Adjusted EBITDA was $47.9 million in 2025 compared to $57.4 million in 2024. Compared to the prior year, Results reflected the impact of the Royal Purple Industrial divestiture; however, excluding the divested business, underlying margin performance improved year-over-year, supported by stronger TruFuel results driven by stabilized input costs and resilient pricing This segment continues to strengthen its position in consumer channels. The prior year also included $5.8 million of insurance proceeds that did not recur in 2025.

Corporate segment Adjusted EBITDA was negative $77.7 million in 2025 versus negative $72.9 million in 2024 primarily due to higher labor and benefits related expenses.

Liquidity Update

As of December 31, 2025, we had total liquidity of $447.6 million comprised of $125.1 million of unrestricted cash, $80.0 million of restricted cash and $242.5 million of availability under our revolving credit facilities. As of December 31, 2025, our revolving credit facilities had a $412.3 million borrowing base, $94.6 million in outstanding borrowings and $75.2 million of outstanding standby letters of credit. We believe we will continue to have sufficient

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liquidity from cash on hand, projected cash flow from operations, borrowing capacity and other means by which to meet our financial commitments, debt service obligations, contingencies, and anticipated capital expenditures for at least the next 12 months. Read Item 7 “Management’s Discussion and Analysis — Liquidity and Capital Resources” and Part I, Item 1A. “Risk Factors” for additional information.

On January 23, 2026, the Company entered into the Ninth Amendment to the Third Amended and Restated Credit Agreement (the “Ninth Amendment”). Refer to “— Recent Developments — Ninth Amendment to Third Amended and Restated Credit Agreement” for further information.

Renewable Fuel Standard Update

Along with the broader refining industry, we remain subject to compliance costs under the RFS unless or until we receive a small refinery exemption from the EPA, which we have historically received. Administered by the EPA, the RFS provides annual requirements for the total volume of renewable transportation fuels that are mandated to be blended into finished transportation fuels. If a refiner does not meet its required annual Renewable Volume Obligation, the refiner can purchase blending credits in the open market, referred to as RINs. For more information, see Part I, Item 1A, “Risk Factors — The availability and cost of renewable identification numbers and results of litigation related to our SRE petitions could have a material adverse effect on our results of operations and financial condition and our ability to make payments on our debt obligations.”

For the year ended December 31, 2025, we recorded a gain of $114.1 million for RINs, as compared to a gain of $31.9 million for RINs for the year ended December 31, 2024. The fiscal year 2025 gain reflects a reduction in the RINs Obligation liability recorded on the Company’s consolidated balance sheets as a result of the Small Refinery Exemptions received from EPA in August 2025, partially off-set by a significant increase in RINs prices. The fiscal year 2024 gain reflects a reduction in the RINs Obligation liability recorded on the Company’s consolidated balance sheets, primarily due to lower RINs prices. Our gross RINs Obligation, which includes RINs that are required to be secured through either our own blending or through the purchase of RINs in the open market, is spread across four compliance categories (D3, D4, D5 and D6). The gross RINs obligations may be satisfied by our own renewables blending, RIN purchases, or receipt of small refinery exemptions.

Expenses related to RFS compliance have the potential to remain a significant expense for our two segments containing fuels products. If legal or regulatory changes occur that have the effect of increasing our RINs Obligation or eliminating or narrowing the availability of the small refinery exemption under the RFS program, we could be required to purchase additional RINs in the open market, which may materially increase our costs related to RFS compliance and could have a material adverse effect on our results of operations and liquidity.

Unrestricted Subsidiaries

Refer to Note 19 — “Unrestricted Subsidiaries” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information regarding certain financial information of our unrestricted subsidiaries.

Key Performance Measures

Our sales and results of operations are principally affected by demand for specialty products, fuel and renewable fuel product demand, global fuel crack spreads, the price of natural gas used as fuel in our operations, our ability to operate our production facilities at high utilization, and our results from derivative instrument activities.

Our primary raw materials are crude oil, renewable feedstocks and other specialty feedstocks, and our primary outputs are specialty consumer facing and industrial products, specialty branded products, and fuel and renewable fuel products. The prices of crude oil, specialty products and fuel and renewable fuel products are subject to fluctuations in response to changes in supply, demand, market uncertainties and a variety of factors beyond our control. We monitor these risks and

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from time-to-time enter into derivative instruments designed to help mitigate the impact of commodity price fluctuations on our business. The primary purpose of our commodity risk management activities is to economically hedge our cash flow exposure to commodity price risk. We may also hedge when market conditions exist that we believe to be out of the ordinary and particularly supportive of our financial goals. We enter into derivative contracts for future periods in quantities that do not exceed our projected purchases of crude oil and natural gas and sales of fuel products. Read Note 9 — “Derivatives” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements.”

Our management uses several financial and operational measurements to analyze our performance. These measurements include the following:

●

sales volumes;

●

segment gross profit;

●

segment Adjusted gross profit;

●

segment Adjusted EBITDA;

●

segment Adjusted EBITDA with Tax Attributes; and

●

selling, general and administrative expenses.

Sales volumes. We view the volumes of Specialty Products and Solutions products, Montana/Renewables products and Performance Brands products sold as an important measure of our ability to effectively utilize our operating assets. Our ability to meet the demands of our customers is driven by the volumes of feedstocks that we run at our facilities. Higher volumes typically improve profitability both through the spreading of fixed costs over greater volumes and the additional gross profit achieved on the incremental volumes.

Segment gross profit. Specialty Products and Solutions, Montana/Renewables and Performance Brands products’ gross profit are important measures of profitability of our segments. We define gross profit as sales less the cost of crude oil and other feedstocks, LCM/LIFO adjustments, and other production-related expenses, the most significant portion of which includes labor, plant fuel, utilities, contract services, maintenance, transportation, RINs, depreciation and amortization and processing materials. We use gross profit as an indicator of our ability to manage margins in our business over the long-term. The increase or decrease in selling prices typically lags behind the rising or falling costs, respectively, of feedstocks throughout our business. Other than plant fuel, RINs mark-to-market adjustments, and LCM/LIFO adjustments, production related expenses generally remain stable across broad ranges but can fluctuate depending on maintenance activities performed during a specific period.

Segment Adjusted gross profit. Specialty Products and Solutions, Montana/Renewables and Performance Brands products segment Adjusted gross profit measures are useful as they exclude transactions not related to our core cash operating activities and provide metrics to analyze the profitability of the core cash operations of our segments. We define segment Adjusted gross profit as segment gross profit excluding the impact of (a) LCM inventory adjustments; (b) the impact of liquidation of inventory layers calculated using the LIFO method; (c) RINs mark-to-market adjustments; (d) RINs incurrence expense; (e) depreciation and amortization; and (f) all extraordinary, unusual or non-recurring items of revenue or cost of sales.

Segment Adjusted EBITDA and Segment Adjusted EBITDA with Tax Attributes. We believe that Specialty Products and Solutions, Montana/Renewables and Performance Brands segment Adjusted EBITDA and Adjusted EBITDA with Tax Attributes measures are useful as they exclude transactions not related to our core cash operating activities and provide metrics to analyze our ability to pay interest to our noteholders. Adjusted EBITDA and Adjusted EBITDA with Tax Attributes allows us to meaningfully analyze the trends and performance of our core cash operations as well as to make

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decisions regarding the allocation of resources to segments. Corporate Adjusted EBITDA primarily reflects general and administrative costs.

Results of Operations

Production Volume. The following table sets forth information about our continuing operations after giving effect to the elimination of all intercompany activity. Facility production volume differs from sales volume due to changes in inventories and the sale of purchased blendstocks such as ethanol and specialty blendstocks, as well as the resale of crude oil.


	Year Ended December 31,
	2025		2024		2023

	(In bpd)
Total sales volume ⁽¹⁾	90,468		88,007		79,805
Facility production:
Specialty Products and Solutions:
Lubricating oils	12,012		11,927		10,358
Solvents	7,675		7,494		7,208
Waxes	1,405		1,415		1,326
Fuels, asphalt and other by-products	39,537		36,390		37,353
Total Specialty Products and Solutions	60,629		57,226		56,245
Montana/Renewables:
Gasoline	3,480		3,556		3,898
Diesel	2,642		2,830		2,941
Jet fuel	525		472		449
Asphalt, heavy fuel oils and other	3,779		3,983		4,483
Renewable fuels	11,270		9,848		6,314
Total Montana/Renewables	21,696		20,689		18,085

Performance Brands	1,570		1,739		1,474

Total facility production	83,895		79,654		75,804

(1)	Total sales volume includes sales from the production at our facilities and certain third-party facilities pursuant to supply and/or processing agreements, sales of inventories and the resale of crude oil to third-party customers. Total sales volume includes the sale of purchased blendstocks.

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The following table reflects our consolidated results of operations and includes the non-GAAP financial measures EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes. For a reconciliation of EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes to Net income (loss), our most directly comparable financial performance measure calculated and presented in accordance with GAAP, read “Non-GAAP Financial Measures” (in millions):


	Year Ended December 31,
		2025		2024		2023

Sales	$	4,137.1	$	4,189.4	$	4,181.0
Cost of sales		3,891.4		3,958.6		3,729.3
Gross profit		245.7		230.8		451.7
Operating costs and expenses:
Selling		47.9		55.7		54.9
General and administrative		123.8		145.5		133.0
Taxes other than income taxes		19.8		20.7		21.5
Loss on impairment and disposal of assets		1.3		2.0		3.5
Gain on sale of business		(55.8)		—		—
Other operating income		—		(1.2)		(28.4)
Operating income		108.7		8.1		267.2
Other income (expense):
Interest expense		(215.8)		(236.7)		(221.7)
Debt extinguishment costs		(47.4)		(0.4)		(5.9)
Gain on derivative instruments		8.7		9.3		9.9
Other income (expense):		19.4		(1.5)		0.2
Total other expense		(235.1)		(229.3)		(217.5)
Net income (loss) before income taxes		(126.4)		(221.2)		49.7
Income tax (benefit) expense		(92.6)		0.8		1.6
Net income (loss)	$	(33.8)	$	(222.0)	$	48.1
EBITDA	$	238.3	$	164.5	$	418.3
Adjusted EBITDA	$	211.2	$	229.3	$	354.5
Adjusted EBITDA with Tax Attributes	$	293.3	$	229.3	$	354.5

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Non-GAAP Financial Measures

We include in this Annual Report the non-GAAP financial measures EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes. We provide reconciliations of EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes to Net income (loss), our most directly comparable financial performance measure calculated and presented in accordance with GAAP.

EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes are used as supplemental financial measures by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others, to assess:

●

the financial performance of our assets without regard to financing methods, capital structure or historical cost basis;

●

the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness;

●

our operating performance and return on capital as compared to those of other companies in our industries, without regard to financing or capital structure; and

●

the viability of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities.

We believe that these non-GAAP measures are useful to analysts and investors as they exclude transactions not related to our core cash operating activities and provide metrics to analyze our ability to pay interest to our noteholders. However, the indentures governing our senior notes contain covenants that, among other things, restrict our ability to pay dividends. We believe that excluding these transactions allows investors to meaningfully analyze trends and performance of our core cash operations.

We define EBITDA for any period as net income (loss) plus interest expense (including amortization of debt issuance costs), income taxes and depreciation and amortization. We believe net income (loss) is the most directly comparable GAAP measure to EBITDA.

During the first quarter of 2025, the CODM changed the definition and calculation of Adjusted EBITDA to exclude RINs incurrence expense (see item (k) below). The Company’s RINs incurrence expense is calculated by multiplying the RINs obligation in the period incurred (based on actual results) by the spot price on the day the RINs obligation is incurred for each accounting period. The resulting non-cash incurrence expenses are included in cost of sales in the statements of operations. The Company believes that this revised definition and calculation better reflects the performance of the Company’s business segments including cash flows because it excludes these non-cash fluctuations. Adjusted EBITDA has been revised for all periods presented to consistently reflect this change. For all periods presented in the Company’s consolidated balance sheets and consolidated results of operations, we did not purchase any RINs.

We define Adjusted EBITDA for any period as EBITDA adjusted for (a) impairment; (b) unrealized gains and losses from mark-to-market accounting for hedging activities; (c) realized gains and losses under derivative instruments excluded from the determination of net income (loss); (d) non-cash equity-based compensation expense and other non-cash items (excluding items such as accruals of cash expenses in a future period or amortization of a prepaid cash expense) that were deducted in computing net income (loss); (e) debt refinancing fees, extinguishment costs, premiums and penalties; (f) any net gain or loss realized in connection with an asset sale that was deducted in computing net income (loss); (g) amortization of turnaround costs; (h) LCM inventory adjustments; (i) the impact of liquidation of inventory layers calculated using the LIFO method; (j) RINs mark-to-market adjustments; (k) RINs incurrence expense; and (l) all extraordinary, unusual or non-recurring items of gain or loss, or revenue or expense.

We define Adjusted EBITDA Margin as Adjusted EBITDA divided by sales.

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We define Adjusted EBITDA with Tax Attributes for any period as Adjusted EBITDA plus the notional value of CFPCs, less the difference between the notional value of any CFPCs sold and the amount realized from such sales during the period.

The definition of Adjusted EBITDA presented in this Annual Report is similar to the calculation of “Consolidated Cash Flow” contained in the indentures governing our senior notes. We are required to report Consolidated Cash Flow to the holders of our senior notes and Adjusted EBITDA to the lenders under our revolving credit facility, and these measures are used by them to determine our compliance with certain covenants governing those debt instruments. Read “Liquidity and Capital Resources — Debt and Credit Facilities” for additional details regarding the covenants governing our debt instruments.

EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes should not be considered alternatives to Net income (loss) or Operating income (loss) or any other measure of financial performance presented in accordance with GAAP. In evaluating our performance as measured by EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes, management recognizes and considers the limitations of these measurements. EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes do not reflect our liabilities for the payment of income taxes, interest expense or other obligations such as capital expenditures. Accordingly, EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes are only two of several measurements that management utilizes. Moreover, our definition of EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes may not be comparable to similarly titled measures of another company because all companies may not calculate EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes in the same manner.

The following tables present a reconciliation of Net income (loss), our most directly comparable GAAP financial performance measure to EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes for each of the periods indicated (in millions).


		Year Ended December 31,
		2025			2024			2023


Reconciliation of Net income (loss) to EBITDA, Adjusted EBITDA, and Adjusted EBITDA with Tax Attributes
Net income (loss)		$	(33.8)		$	(222.0)		$	48.1
Add:
Interest expense			215.8			236.7			221.7
Depreciation and amortization			148.9			149.0			146.9
Income tax (benefit) expense			(92.6)			0.8			1.6
EBITDA		$	238.3		$	164.5		$	418.3
Add:
LCM / LIFO loss		$	19.9		$	12.3		$	35.6
Unrealized gain on derivative instruments			(24.0)			(47.1)		$	(33.0)
Debt extinguishment costs			47.4			0.4			5.9
Amortization of turnaround costs			41.0			38.0			36.1
Loss on impairment and disposal of assets			1.3			2.0			3.5
Gain on sale of business			(55.8)			—			—
RINs incurrence (gain) expense			(232.0)			34.5			94.0
RINs mark-to-market (gain) loss			156.0			(66.4)			(290.2)
Equity-based compensation and other items			14.4			19.7			20.2
Other ⁽¹⁾			(8.1)			75.5			60.9
Noncontrolling interest adjustments			12.8			(4.1)			3.2
Adjusted EBITDA		$	211.2		$	229.3		$	354.5
Tax attributes ⁽²⁾			82.1			—			—
Adjusted EBITDA with Tax Attributes		$	293.3		$	229.3		$	354.5

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(1)

For the year ended December 31, 2024, other non-recurring expenses included a $51.3 million realized loss on derivatives related to our inventory financing arrangements. For the year ended December 31, 2023, other non-recurring expenses included a $50.6 million charge to cost of sales for losses under firm purchase commitments.

(2)

Tax attribute amounts reflect 100% of the notional value of CFPCs generated for each respective period presented less any discounts on the sale of CFPCs. The CFPCs can be realized by applying the credits to the Company’s federal income tax liability or sold in a secondary market at a discounted rate.

The following table presents a reconciliation of Montana/Renewables Segment Net income (loss), our most directly comparable GAAP financial performance measure to Montana/Renewables Segment Adjusted EBITDA and Montana/Renewables Segment Adjusted EBITDA with Tax Attributes for each of the periods indicated (in millions).


		Year Ended December 31,
		2025		2024			2023


Reconciliation of Montana/Renewables Segment Net income (loss) to Segment Adjusted EBITDA and Segment Adjusted EBITDA with Tax Attributes:
Montana/Renewables Segment Net loss		$	(145.1)	$	(158.4)		$	(137.0)
Add:
Depreciation and amortization		$	109.5	$	106.8		$	95.2
LCM / LIFO loss			1.7		11.5			35.7
Loss on impairment and disposal of assets			—		1.1			3.5
Interest expense			63.8		70.4			65.4
Debt extinguishment costs			47.5		—			0.4
Unrealized gain on derivatives			—		—			(4.6)
RINs incurrence (gain) expense			(94.1)		5.6			22.3
RINs mark-to-market (gain) loss			47.4		(21.4)			(89.1)
Other			(6.3)		10.8			57.5
Equity-based compensation and other items			5.6		—			—
Income tax benefit			(93.6)		—			—
Noncontrolling interest adjustments			12.8		(4.1)			3.2
Montana/Renewables Segment Adjusted EBITDA		$	(50.8)	$	22.3		$	52.5
Tax attributes ⁽¹⁾			82.1		—			—
Montana/Renewables Segment Adjusted EBITDA with Tax Attributes		$	31.3	$	22.3		$	52.5

(1)

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Year Ended December 31, 2025, Compared to Year Ended December 31, 2024

Sales. Sales decreased $52.3 million, or 1.2%, to $4,137.1 million in 2025 from $4,189.4 million in 2024. Sales for each of our principal product categories in these periods were as follows (in millions, except barrel and per barrel data):


		Year Ended December 31,
		2025			2024		% Change
Sales by segment:
Specialty Products and Solutions:
Lubricating oils		$	752.0		$	788.6	(4.6)	%
Solvents			401.6			407.3	(1.4)	%
Waxes			152.4			156.3	(2.5)	%
Fuels, asphalt and other by-products ⁽¹⁾			1,327.0			1,437.1	(7.7)	%
Total Specialty Products and Solutions		$	2,633.0		$	2,789.3	(5.6)	%
Total Specialty Products and Solutions sales volume (in barrels)			23,194,000			22,868,000	1.4	%
Average Specialty Products and Solutions sales price per barrel		$	113.52		$	121.97	(6.9)	%
Montana/Renewables:
Gasoline		$	128.1		$	140.8	(9.0)	%
Diesel			102.6			114.6	(10.5)	%
Jet Fuel			19.6			18.2	7.7	%
Asphalt, heavy fuel oils and other ⁽²⁾			159.0			159.6	(0.4)	%
Renewable fuels			783.8			631.7	24.1	%
Total Montana/Renewables		$	1,193.1		$	1,064.9	12.0	%
Total Montana/Renewables sales volume (in barrels)			9,236,000			8,717,000	6.0	%
Average Montana/Renewables sales price per barrel		$	129.18		$	122.16	5.7	%
Performance Brands:
Total Performance Brands⁽³⁾		$	311.0		$	335.2	(7.2)	%
Total Performance Brands sales volume (in barrels)			591,000			626,000	(5.6)	%
Average Performance Brands sales price per barrel		$	526.23		$	535.46	(1.7)	%

Total sales		$	4,137.1		$	4,189.4	(1.2)	%
Total Specialty Products and Solutions, Montana/Renewables, and Performance Brands sales volume (in barrels)			33,021,000			32,211,000	2.5	%

(1)	Represents (a) by-products, including fuels and asphalt, produced in connection with the production of specialty products at the Shreveport, Princeton, Cotton Valley, Dickinson and Karns City facilities, and (b) polyol ester synthetic lubricants produced at the Missouri facility.

(2)	Represents asphalt, heavy fuel oils and other products produced in connection with the production of fuels at the Montana specialty asphalt facility.

(3)	Represents packaged and synthetic specialty products at our Royal Purple, Bel-Ray and Calumet Packaging facilities.

The components of the $156.3 million decrease in Specialty Products and Solutions segment sales in 2025, as compared to 2024, were as follows (in millions):


		Dollar Change
Sales price		$	(196.1)
Volume			39.8
Total Specialty Products and Solutions segment sales decrease		$	(156.3)

Specialty Products and Solutions segment sales decreased period over period primarily due to lower crude oil prices in the current year period. This impact was partially offset by improved operational reliability across our integrated asset

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base, resulting in higher throughput volumes. Our throughput volumes increased in the current year, despite a planned turnaround at our Shreveport facility in June 2025.

The components of the $128.2 million increase in Montana/Renewables segment sales in 2025, as compared to 2024, were as follows (in millions):


		Dollar Change
Sales price		$	64.7
Volume			63.5
Total Montana/Renewables segment sales increase		$	128.2

Montana/Renewables segment sales increased due to improved operational reliability. Further, current year results were favorably impacted by higher renewable fuels product prices at our Montana Renewables facility in comparison to the prior year.

The components of the $24.2 million decrease in Performance Brands segment sales in 2025, as compared to 2024, were as follows (in millions):


		Dollar Change
Sales price		$	(5.3)
Volume			(18.9)
Total Performance Brands segment sales decrease		$	(24.2)

Performance Brands segment sales decreased primarily due to lower sales volumes as a result of the divestiture of the Royal Purple Industrial business.

Gross Profit. Gross profit increased $14.9 million, or 6.5%, to $245.7 million in 2025 from $230.8 million in 2024. Gross profit for our business segments were as follows (in millions, except per barrel data):


		Year Ended December 31,
		2025			2024			% Change
Gross profit by segment:
Specialty Products and Solutions:
Gross profit		$	265.7		$	189.0		40.6	%
Percentage of sales			10.1	%		6.8	%	3.3	%
Specialty Products and Solutions gross profit per barrel		$	11.46		$	8.26		38.7	%
Montana/Renewables:
Gross loss		$	(98.2)		$	(53.5)		83.6	%
Percentage of sales			(8.2)	%		(5.0)	%	(3.2)	%
Montana/Renewables gross loss per barrel		$	(10.63)		$	(6.14)		73.2	%
Performance Brands:
Gross profit		$	78.2		$	95.3		(17.9)	%
Percentage of sales			25.1	%		28.4	%	(3.3)	%
Performance Brands gross profit per barrel		$	132.32		$	152.24		(13.1)	%

Total gross profit		$	245.7		$	230.8		6.5	%
Percentage of sales			5.9	%		5.5	%	0.4	%

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The components of the $76.7 million increase in Specialty Products and Solutions segment gross profit in 2025, as compared to 2024, were as follows (in millions):


		Dollar Change
Year ended December 31, 2024 reported gross profit		$	189.0
Cost of materials			267.9
Operating costs (excl. RINs)			(26.1)
LCM / LIFO inventory adjustments			(17.2)
Volumes			7.7
Sales price			(196.1)
RINs			40.5
Year ended December 31, 2025 reported gross profit		$	265.7

The increase in Specialty Products and Solutions segment gross profit for the year ended December 31, 2025, as compared to the same period in 2024, was primarily reflective of the strengthened commodity margin environment for fuels products, coupled with lower crude prices and improved asset reliability. Additionally, results were favorably impacted by the de-recognition of the RINs Obligation on the Company’s balance sheet for the SRE exemptions received by the EPA in August 2025. Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information related to our accounting for RINs.

The components of the $44.7 million decrease in Montana/Renewables segment gross profit (loss) in 2025, as compared to 2024, were as follows (in millions):


	Dollar Change
Year ended December 31, 2024 reported gross profit (loss)	$	(53.5)
Cost of materials		(201.0)
LCM / LIFO inventory adjustments		9.8
Volumes		12.4
RINs		41.7
Operating costs (excl. RINs)		27.7
Sales price		64.7
Year ended December 31, 2025 reported gross profit (loss)	$	(98.2)

The decrease in Montana/Renewables segment gross profit (loss) for the year ended December 31, 2025, as compared to the same period in 2024, was primarily due to the unfavorable impact associated with cost of materials as a result of the regulatory change from BTC to CFPC. The change from BTC to CFPC resulted in the tax credit benefit of the CFPC recorded in income tax expense (benefit) and not gross profit. Our income tax benefit for fiscal year 2025 was $93.6 million. In the prior year period, Montana Renewables’ benefit from the BTC was reflected in gross profit. Our Montana specialty asphalt business was favorably impacted by the continued export of wholesale volumes and improvements in crack spreads. The segment as a whole benefited from continued focus on operating cost efficiency, highlighted by the significant cost reductions for wash water and process materials as a result of improving certain operating unit efficiency at both our Montana Renewables facility and legacy Montana specialty asphalt facility.

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The components of the $17.1 million decrease in Performance Brands segment gross profit in 2025, as compared to 2024, were as follows (in millions):


		Dollar Change
Year ended December 31, 2024 reported gross profit		$	95.3
Sales price			(5.3)
Operating costs			(4.6)
LCM / LIFO inventory adjustments			(0.2)
Volume			(7.0)
Cost of materials			—
Year ended December 31, 2025 reported gross profit		$	78.2

The decrease in Performance Brands segment gross profit for the year ended December 31, 2025, as compared to the same period in 2024, was primarily due to the divestiture of the Royal Purple Industrial business in the current year period. This segment continues to benefit from strong unit margins, reflective of stabilized input costs in our branded and consumer markets. The prior year also included $5.8 million of insurance proceeds that did not recur in 2025.

General and administrative. General and administrative expenses decreased $21.7 million, or 14.9%, to $123.8 million in 2025 from $145.5 million in 2024. The decrease was due primarily to a $20.8 million decrease in equity-based compensation related expenses and a $5.8 million decrease in professional services fees.

Gain on sale of business. There was a $55.8 million gain on sale of business in 2025 for the sale of assets related to the industrial portion of the Royal Purple® business. There was no gain or loss for the sale of a business recorded in the same period in 2024. Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information related to the sale of assets for the industrial portion of the Royal Purple® business.

Interest expense. Interest expense decreased $20.9 million, or 8.8%, to $215.8 million in 2025 from $236.7 million in 2024. The decrease was due to lower interest rates on the Company’s outstanding debt facilities in the current year in comparison to the prior year period. Further, the decrease in interest expense was favorably impacted by lower borrowings on our revolving credit facility during the current year period in comparison to the prior year.

Debt extinguishment costs. There was a $47.4 million expense for debt extinguishment costs in 2025 related to the DOE Loan and subsequent repurchase of the equipment associated with the MRL Asset Financing Arrangements, repayment of outstanding loans under the MRL Term Loan Credit Agreement and MRL Revolving Credit Agreement and repayment of outstanding obligations under the MRL Supply and Offtake Agreement. Debt extinguishment expense recorded in the same period in 2024 was a de-minimus amount. Refer to Note 8 — “Long-Term Debt” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

Year Ended December 31, 2024, Compared to Year Ended December 31, 2023

Refer to Item 7 “Management’s Discussion and Analysis — Year Ended December 31, 2024, Compared to Year Ended December 31, 2023” of our 2024 Annual Report for a description of the factors impacting our results of operations for the year ended December 31, 2024 in comparison to the year ended December 31, 2023.

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Liquidity and Capital Resources

Our principal sources of cash have historically included cash flow from operations, proceeds from public equity offerings, proceeds from notes offerings, bank borrowings and other financial arrangements. Principal uses of cash have included capital expenditures, working capital needs, acquisitions, and debt service. We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions, tender offers or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

In general, we expect that our short-term liquidity needs, including debt service, working capital, replacement and environmental capital expenditures and capital expenditures related to internal growth projects, will be met primarily through cash on hand, projected cash flow from operations, borrowing capacity under our revolving credit facility and asset sales.

On January 6, 2025, the Company entered into the Seventh Amendment to the Credit Agreement to allow for permitted additional investments in MRHL not to exceed $170.0 million in an aggregate amount at any time outstanding in connection with the DOE Facility.

On January 10, 2025, MRL and the U.S. Department of Energy (the “DOE”), as guarantor and loan servicer, executed a Loan Guarantee Agreement (the “DOE Loan”) for a $1.44 billion guaranteed loan facility to fund the construction and expansion of the renewable fuels facility owned by MRL. The loan guarantee is structured in two tranches, with the first tranche of approximately $781.8 million disbursed on February 18, 2025 (the “Funding Date”) to fund eligible expenses previously incurred by MRL.

On the Funding Date, the Company used a portion of the proceeds from the first tranche of the DOE Facility to:

●

repurchase all of the equipment associated with the MRL Asset Financing Arrangements for approximately $392.3 million (including exit fees of $23.0 million);

●

repay in full the outstanding loans of approximately $83.8 million under the MRL Term Loan Credit Agreement (including a make-whole premium of approximately $9.4 million and an early termination premium of approximately $0.7 million);

●

repay in full the outstanding loans of approximately $26.7 million under the MRL Revolving Credit Agreement; and

●

repay in full the outstanding obligations of approximately $32.5 million under the MRL Supply and Offtake Agreement.

In addition, on the Funding Date, the Company received the remaining purchase price of $40.0 million from Stonebriar with regards to the Montana Refinery Asset Financing Arrangement.

MRL has the ability to draw additional tranches of up to approximately $658.0 million through a delayed draw construction facility. Borrowings under the DOE Loan are obligations of our unrestricted subsidiaries MRL and MRHL solely, and are non-recourse to the Company and its restricted subsidiaries. Refer to Note 8 — “Long-Term Debt” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

On January 16, 2025, the Issuers issued $100.0 million aggregate principal amount of a new series of the Issuers’ 9.75% Senior Notes due 2028 in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act. The 2028 Mirror Issuance Notes were issued at 98% of par for net proceeds of approximately $96.0 million, after deducting the initial purchasers’ discount and estimated offering expenses. The Company used the net proceeds from the offering of the 2028 Mirror Issuance Notes to redeem a portion of the Issuers’ outstanding 2026 Notes on May 24, 2025. Refer to Note 8 — “Long-Term Debt” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

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On February 28, 2025, the Company announced that it entered into a definitive agreement with a wholly owned subsidiary of Lubrication Engineers, Inc., a portfolio company of Aurora Capital Partners, to sell assets related to the industrial portion of its Royal Purple® business, for $110.0 million, subject to certain customary adjustments. The Company retained the consumer portion of the Royal Purple® business. At the closing of the transaction on December 31, 2025, the Company received cash proceeds of $96.9 million, with a remaining deferred payment of $1.5 million to be received in 2026, net of working capital adjustments and transaction related expenses. During 2025, the Company recorded a $55.8 million gain on the sale of business in the consolidated statements of operations. Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

On July 25, 2025, in connection with the Shreveport Terminal Asset Financing Arrangement, the Company entered into the Eighth Amendment to the Third Amended and Restated Credit Agreement, to among other changes, modify the Credit Agreement to permit separately the indebtedness and liens arising from the Shreveport Terminal Asset Financing Arrangement.

On January 12, 2026, the Partnership and Finance Corp. issued $405.0 million aggregate principal amount of 2031 Notes. Refer to “— Recent Developments — 9.75% Senior Notes due 2031” for additional information.

We are forecasting total capital expenditures of approximately $130.0 million to $160.0 million in 2026. Our forecasted capital expenditures are primarily related to maintenance and reliability projects and capital expenditures associated with MaxSAF™. We anticipate that capital expenditure requirements for the MaxSAF™ project will be funded by MRL, an unrestricted subsidiary of the Company, through cash flows from operations, cash on hand and borrowings under the DOE Facility. We anticipate that capital expenditure requirements for our restricted subsidiaries group will be provided primarily through cash flows from operations, cash on hand, and by available borrowings under our revolving credit facility. If future capital expenditures require amounts in excess of our then-current cash flow from operations and borrowing availability under our revolving credit facility, we may be required to issue debt or equity securities in public or private offerings or incur additional borrowings under bank credit facilities to meet those costs.

The borrowing base on our revolving credit facilities decreased from approximately $472.1 million as of December 31, 2024, to approximately $412.3 million at December 31, 2025. Our borrowing availability increased from approximately $140.1 million at December 31, 2024, to approximately $242.5 million at December 31, 2025. Total liquidity, consisting of unrestricted cash, restricted cash and available funds under our revolving credit facilities, increased from $178.2 million at December 31, 2024 to $447.6 million at December 31, 2025.

On January 23, 2026, the Company entered into the Ninth Amendment to the Third Amended and Restated Credit Agreement. Refer to “— Recent Developments — Ninth Amendment to Third Amended and Restated Credit Agreement” for additional information.

Cash Flows from Operating, Investing and Financing Activities

We believe that we have sufficient liquid assets, cash flow from operations, borrowing capacity and adequate access to capital markets to meet our financial commitments, debt service obligations and anticipated capital expenditures for at least the next 12 months. We continue to seek to lower our operating costs, selling expenses and general and administrative expenses as a means to further improve our cash flow from operations with the objective of having our cash flow from operations support all of our capital expenditures and interest payments. However, we are subject to business and operational risks that could materially adversely affect our cash flows. A material decrease in our cash flow from operations including a significant, sudden decrease in crude oil prices would likely produce a corollary effect on our borrowing capacity under our revolving credit facility and potentially our ability to comply with the covenants under our revolving credit facility. A significant, sudden increase in crude oil prices, if sustained, would likely result in increased working capital requirements which would be funded by borrowings under our revolving credit facility. In addition, our cash flow from operations may be impacted by the timing of settlement of our derivative activities. Gains and losses from derivative instruments that do not qualify as cash flow hedges are recorded in unrealized gain (loss) on derivative instruments until settlement and will impact operating cash flow in the period settled.

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The following table summarizes our primary sources and uses of cash in each of the most recent two years (in millions):


		Year Ended December 31,
		2025			2024


Net cash provided by (used in) operating activities		$	108.9		$	(46.4)
Net cash provided by (used in) investing activities			44.1			(76.7)
Net cash provided by financing activities			6.2			154.3
Net increase in cash, cash equivalents and restricted cash		$	159.2		$	31.2

Operating Activities. Operating activities provided cash of $108.9 million in 2025 compared to using cash of $46.4 million in 2024. This change was primarily related to an increase in net income (loss), after adjusting for non-cash items, in the current year period.

Investing Activities. Investing activities provided cash of $44.1 million in 2025 compared to a use of cash of $76.7 million in 2024. The change is related to the net proceeds received for the sale of the Royal Purple Industrial business in the current year period. Cash expenditures for additions to property, plant and equipment in the current year period were less than the prior year as a result of lower replacement capital expenditure requirements.

Financing Activities. Financing activities provided cash of $6.2 million in 2025 compared to providing cash of $154.3 million in 2024. The change is primarily due to the borrowings we received in the current year period from the DOE Loan, 2028 Mirror Issuance Notes, and Shreveport Terminal Asset Financing Arrangement, offset by the payments we made in the current year to repay outstanding borrowings under the revolving credit agreement, repurchase the equipment associated with the MRL Asset Financing Arrangements, repay the outstanding loans under the MRL Term Loan Credit Agreement and MRL Revolving Credit Agreement, repay the outstanding obligations under the MRL Supply and Offtake Agreement, and partially redeem the 2026 Notes. Cash provided by financing activities in the prior year period primarily consisted of borrowings under the revolving credit facility and proceeds from the issuance of the 2029 Secured Notes, borrowings from the Montana terminal asset financing arrangement and the Montana refinery asset financing arrangement, the impacts of which were partially offset by repayments of the 2024 Secured Notes and 2025 Notes.

Capital Expenditures

Our property, plant and equipment capital expenditure requirements consist of capital improvement expenditures, replacement capital expenditures, environmental capital expenditures and turnaround capital expenditures. Capital improvement expenditures include the acquisition of assets to grow our business, facility expansions, or capital initiatives that reduce operating costs. Replacement capital expenditures replace worn out or obsolete equipment or parts. Environmental capital expenditures include asset additions to meet or exceed environmental and operating regulations. Turnaround capital expenditures represent capitalized costs associated with our periodic major maintenance and repairs.

The following table sets forth our capital improvement expenditures, replacement capital expenditures, environmental capital expenditures and turnaround capital expenditures in each of the periods shown, including capitalized interest (in millions):


		Year Ended December 31,
		2025		2024		2023


Capital improvement expenditures		$	13.1	$	15.7	$	190.6
Replacement capital expenditures			37.2		56.6		69.9
Environmental capital expenditures			2.0		4.4		11.3
Turnaround capital expenditures			24.4		20.6		47.9
Total		$	76.7	$	97.3	$	319.7

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2026 Capital Spending Forecast

Debt and Credit Facilities

As of December 31, 2025, our primary debt and credit instruments consisted of:

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$650.0 million senior secured revolving credit facility maturing in January 2027 (after giving effect to the Fourth Amendment to our revolving credit facility (the “Credit Facility Amendment”)), subject to borrowing base limitations, with a maximum letter of credit sub-limit equal to $255.0 million, which amount may be increased to 90% of revolver commitments in effect with the consent of the Agent (as defined in the Credit Agreement) (“revolving credit facility”);

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$124.4 million of 11.00% Senior Notes due 2026 (“2026 Notes”);

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$325.0 million of 8.125% Senior Notes due 2027 (“2027 Notes”);

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$325.0 million of 9.75% Senior Notes due 2028 (“2028 Notes”);

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$100.0 million of 9.75% Senior Notes due 2028 (“2028 Mirror Issuance Notes”);

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$200.0 million of 9.25% Senior Secured Notes due 2029 (“2029 Secured Notes”);

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$815.4 million of borrowings under our DOE Loan;

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$116.1 million of financing through our Shreveport terminal asset financing arrangement;

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$22.5 million of financing through our Montana terminal asset financing arrangement; and

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$142.7 million of financing through our Montana refinery asset financing arrangement.

We were in compliance with all covenants under our debt instruments in place as of December 31, 2025, and believe we have adequate liquidity to conduct our business.

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On the Funding Date, the Company used a portion of the proceeds from the first tranche of the DOE Facility to:

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repurchase all of the equipment associated with the MRL Asset Financing Arrangements for approximately $392.3 million (including exit fees of $23.0 million);

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repay in full the outstanding loans of approximately $26.7 million under the MRL Revolving Credit Agreement; and

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repay in full the outstanding obligations of approximately $32.5 million under the MRL Supply and Offtake Agreement.

In addition, on the Funding Date, the Company received the remaining purchase price of $40.0 million from Stonebriar with regards to the Montana Refinery Asset Financing Arrangement

MRL has the ability to draw additional tranches of up to approximately $658.0 million through a delayed draw construction facility. Borrowings under the DOE Loan are obligations of our unrestricted subsidiaries MRL and MRHL solely, and are non-recourse to the Company and its restricted subsidiaries. Refer to Note 8 — “Long-Term Debt” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

On January 16, 2025, the Issuers issued $100.0 million aggregate principal amount of a new series of the Issuers’ 9.75% Senior Notes due 2028 in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act. The 2028 Mirror Issuance Notes were issued at 98% of par for net proceeds of approximately $96.0 million, after deducting the initial purchasers’ discount and estimated offering expenses. The Company used the net proceeds from the offering of the 2028 Mirror Issuance Notes to redeem a portion of the Issuers’ outstanding 2026 Notes on May 24, 2025. Refer to Note 8 — “Long-Term Debt” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

On January 12, 2026, the Partnership Finance Corp. issued $405.0 million aggregate principal amount of 2031 Notes in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act of 1933, as amended (the “Securities Act”). The Company subsequently redeemed all of the 2026 Notes and all of the 2027 Notes, on or before January 21, 2026. Refer to Note 21 — “Subsequent Events” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

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On January 23, 2026, the Company entered into the Ninth Amendment to the Third Amended and Restated Credit Agreement. The Ninth Amendment amended the Credit Agreement. Among other changes, the Ninth Amendment modified the Credit Agreement to (i) extend the maturity date to January 23, 2031, (ii) provide for commitments of $500.0 million, subject to borrowing base limitations, (iii) revise certain covenants, representations and warranties, events of default and other terms to permit the Company or one or more of its subsidiaries to consummate one or more new inventory financing transactions, subject in each case to the Company’s satisfaction of certain customary conditions and (iv) provide for a reduction of commitments under the Credit Agreement from $500.0 million to $425.0 million if any such inventory financing transaction is consummated. Refer to Note 21 — “Subsequent Events” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information.

Inventory Financing

On January 17, 2024 (the “Effective Date”), the Company and J. Aron entered into a Monetization Master Agreement (the “Master Agreement”), a related Financing Agreement (the “Financing Agreement”) and Supply and Offtake Agreement (together with the Master Agreement and the Financing Agreement, the “Shreveport Supply and Offtake Agreement”). Pursuant to the Shreveport Supply and Offtake Agreement, J. Aron agreed to, among other things, purchase from the Company, or extend to the Company, financial accommodations secured by crude oil and finished products located at the Company’s Shreveport facility on the Effective Date and from time to time, up to maximum volumes specified for crude oil and categories of finished products, subject to the Company’s repurchase obligations with respect thereto. The Shreveport Supply and Offtake Agreement replaced the Company’s previous inventory financing agreement with Macquarie, which terminated on January 17, 2024. Refer to Note 7 — “Inventory Financing Agreements” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

Short-Term Liquidity

As of December 31, 2025, our principal sources of short-term liquidity were (i) approximately $242.5 million of availability under our revolving credit facilities, (ii) inventory financing agreements related to our Shreveport facility, (iii) $125.1 million of unrestricted cash on hand, and (iv) $80.0 million of restricted cash. Borrowings under our revolving credit facility can be used for, among other things, working capital, capital expenditures, and other lawful partnership purposes including acquisitions. For additional information regarding our revolving credit facility, read Note 8 — “Long-Term Debt” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements.”

Long-Term Financing

In addition to our principal sources of short-term liquidity listed above, subject to market conditions, we may meet our cash requirements through the issuance of long-term notes or additional shares of common stock.

From time to time, we issue long-term debt securities referred to as our senior notes. All of our outstanding senior notes, other than the 2029 Secured Notes, are unsecured obligations that rank equally with all of our other senior debt obligations to the extent they are unsecured. As of December 31, 2025, we had $124.4 million in 2026 Notes, $325.0 million in 2027 Notes, $325.0 million in 2028 Notes, $100.0 million in 2028 Mirror Issuance Notes, and $200.0 million in 2029 Secured Notes outstanding. The 2029 Secured Notes and the related guarantees are secured by a first priority lien (subject to certain exceptions) on all the fixed assets that secure our obligations under the secured hedge agreements, as governed by the Collateral Trust Agreement, which governs how secured hedging counterparties and holders of the 2029 Secured Notes share collateral pledged as security for the payment obligations owed by us to the secured hedging counterparties under their respective master derivatives contracts and the holders of the 2029 Secured Notes. In addition, as of December 31, 2025, $815.4 million of borrowings under our DOE Loan, $116.1 million of financing through our Shreveport terminal asset financing arrangement, $22.5 million of financing through our Montana terminal asset financing

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arrangement, and $142.7 million of financing through our Montana refinery asset financing arrangement. Borrowings under the DOE Loan are obligations of our unrestricted subsidiaries MRL and MRHL solely, and are non-recourse to the Company and its restricted subsidiaries. For additional information regarding our long-term financing arrangements, refer to Note 8 — “Long-Term Debt” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” in this Annual Report.

To date, our debt balances have not adversely affected our operations or our ability to repay or refinance our indebtedness. Based on our historical record, we believe that our capital structure will continue to allow us to achieve our business objectives.

For more information regarding our senior notes, read Note 8 — “Long-Term Debt” under Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” in this Annual Report.

Master Derivative Contracts and Collateral Trust Agreement

Under our credit support arrangements, our payment obligations under all of our master derivatives contracts for commodity hedging generally are secured by a first priority lien on our and our subsidiaries’ real property, plant and equipment, fixtures, intellectual property, certain financial assets, certain investment property, commercial tort claims, chattel paper, documents, instruments and proceeds of the foregoing (including proceeds of hedge arrangements). We had no additional letters of credit or cash margin posted with any hedging counterparty as of December 31, 2025. Our master derivatives contracts and Collateral Trust Agreement (as defined below) continue to impose a number of covenant limitations on our operating and financing activities, including limitations on liens on collateral, limitations on dispositions of collateral and collateral maintenance and insurance requirements. For financial reporting purposes, we do not offset the collateral provided to a counterparty against the fair value of our obligation to that counterparty. Any outstanding collateral is released to us upon settlement of the related derivative instrument liability.

Our various hedging agreements contain language allowing our hedge counterparties to request additional collateral if a specified credit support threshold is exceeded. However, these credit support thresholds are set at levels that would require a substantial increase in hedge exposure to require us to post additional collateral. As a result, we do not expect further increases in fuel products crack spreads or interest rates to significantly impact our liquidity due to requirements to post additional collateral.

Additionally, we have a collateral trust agreement (the “Collateral Trust Agreement”) which governs how secured hedging counterparties and holders of the 2029 Secured Notes share collateral pledged as security for the payment obligations owed by us to the secured hedging counterparties under their respective master derivatives contracts and the holders of the 2029 Secured Notes. The Collateral Trust Agreement limits to $150.0 million the extent to which forward purchase contracts for physical commodities are covered by, and secured under, the Collateral Trust Agreement and the Parity Lien Security Documents (as defined in the Collateral Trust Agreement). There is no such limit on financially settled derivative instruments used for commodity hedging. Subject to certain conditions set forth in the Collateral Trust Agreement, we have the ability to add secured hedging counterparties from time to time.

Credit Ratings

In January 2026, Moody’s Ratings (“Moody’s”) affirmed the Company’s Caa1 Corporate Family Rating (“CFR”). Concurrently, Moody’s affirmed the Caa2 ratings on the Company’s existing senior unsecured notes issued by its wholly owned subsidiary, Calumet Specialty Products Partners, L.P., and rated the Company’s newly issued senior unsecured 2031 Notes as Caa2. The outlook on all ratings was upgraded to stable from negative by Moody’s.

In February 2026, S&P upgraded the Company’s outlook to positive from negative. Similarly, all other ratings were affirmed by S&P. The issue-level ratings remain B and CCC+ for the Company’s senior secured debt and senior unsecured debt, respectively.

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Seasonality Impacts on Liquidity

Critical Accounting Estimates

The preparation of our consolidated financial statements in accordance with GAAP requires us to use estimates and make judgements and assumptions about future events that affect the reported amounts of assets, liabilities, revenue, expenses, and the related disclosures. Considerable judgement is often involved in making these determinations. Critical estimates are those that require the most difficult, subjective or complex judgements in the preparation of the financial statements and the accompanying notes. We evaluate these estimates and judgements on a regular basis. We believe our assumptions and estimates are reasonable and appropriate. However, the use of different assumptions could result in significantly different results and actual results could differ from those estimates. The following discussion of accounting estimates is intended to supplement the Summary of Significant Accounting Policies presented in Note 2 to our consolidated financial statements in Part II, Item 8.

We consider an accounting estimate to be critical if:

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The accounting estimate requires us to make assumptions about matters that are highly uncertain at the time the accounting estimate is made; and

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We reasonably could have used different estimates in the current period, or changes in these estimates are reasonably likely to occur from period to period as new information becomes available, and a change in these estimates would have a material impact on our financial condition or results from operations.

Tax Benefits

We take tax positions in our tax returns from time to time that may not be ultimately allowed by the relevant taxing authority. When we take such positions, we evaluate the likelihood of sustaining those positions and determine the amount of tax benefit arising from such positions, if any, that should be recognized in our financial statements. Tax benefits not recognized by us have a full valuation allowance. The evaluation of tax positions and the determination of the benefit arising from such positions that are recognized in our financial statements requires us to make significant judgments and estimates based on an analysis of complex tax laws and regulations and related interpretations. These judgments and estimates are subject to change due to many factors, including the progress of ongoing tax audits, case law, and changes in legislation.

Environmental Matters

Our operations are subject to extensive environmental regulations by governmental authorities relating primarily to the discharge of materials into the environment, waste management, and pollution prevention measures. Future legislative action and regulatory initiatives could result in changes to required operating permits, additional remedial actions, or increased capital expenditures and operating costs that cannot be assessed with certainty at this time. Accruals for environmental liabilities are based on best estimates of probable future costs using currently available information and applying current regulations, as well as our own internal environmental policies. However, environmental liabilities are difficult to assess and estimate due to uncertainties related to the magnitude of possible remediation, the timing of such remediation, and other factors. Such estimates are subject to change due to many factors, including the identification of new sites requiring remediation, changes in environmental laws and regulations and their interpretation, additional

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information related to the extent and nature of remediation efforts, and potential improvements in remediation technologies.

Inventory Valuation

The cost of our inventories is principally determined under the last-in, first-out (LIFO) method. Our LIFO inventories are carried at the lower of cost or market value. The market value of our LIFO inventories is determined based on the net realizable value of the inventories. We compare the market value of inventories to their cost on an aggregate basis, excluding materials and supplies. In determining the market value of our inventories, we assume that feedstocks are converted into fuels and specialty products, which requires us to make estimates regarding the fuels and specialty products expected to be produced. We apply an estimated selling price to our inventories. If the aggregate market value is less than cost, we recognize a loss for the difference in our statements of operations.

Valuation of Finite Long-Lived Assets

Property, plant and equipment and intangible assets with finite lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. If the estimated undiscounted future cash flows related to the asset are less than the carrying value, we recognize a loss equal to the difference between the carrying value and the estimated fair value, usually determined by the estimated discounted future cash flows of the asset. When a decision has been made to dispose of property, plant and equipment prior to the end of the previously estimated useful life, depreciation estimates are revised to reflect the use of the asset over the shortened estimated useful life.

Estimated undiscounted future cash flows are used for the purpose of testing our finite long-lived assets for impairment. Fair values calculated for the purpose of measuring impairments on finite long-lived assets are estimated using the expected present value of future cash flows method and comparative market prices when appropriate. Significant judgment is involved in estimating undiscounted future cash flows and performing these fair value estimates since the results are based on forecasted assumptions.

We base our estimated undiscounted future cash flows and fair value estimates on projected financial information which we believe to be reasonable. However, actual results may differ from these projections.

Valuation of Renewable Identification Numbers (“RINs”) Obligation

The Company’s RINs volume obligation (“RVO” or “RINs Obligation”) is an estimated provision if future purchase of RINs were to be required in order to satisfy the U.S. Environmental Protection Agency’s (“EPA”) requirement to blend renewable fuels into certain transportation fuel products pursuant to the Renewable Fuel Standard (“RFS”) of the Clean Air Act (“CAA”). The Company has historically not been obligated to make these purchases. A RIN is a 38 character number assigned to each physical gallon of renewable fuel produced in or imported into the United States. The EPA sets annual volume obligations for the percentage of renewable fuels that must be blended into transportation fuels consumed in the U.S. Compliance is demonstrated by tendering RINs to the EPA, documenting that blending has been accomplished, or by obtaining a Small Refinery Exemption (“SRE”) as provided in the Clean Air Act. Prior to 2018, the Company historically received the Small Refinery Exemption after qualifying on the merits. As of January 1, 2025, the Company’s petitions for the Small Refinery Exemption for compliance years 2018-2022 were included in blanket denials by EPA across the entire industry; EPA’s denials of Calumet’s 2018-2020 petitions had been overturned in litigation and remanded to EPA; the Company’s cases challenging EPA’s denials for program years 2021 and 2022 were pending in the Fifth Circuit and D.C. Circuit; the 2023 petitions had been denied by the EPA and were the subject of new legal proceedings; and the 2024 petition was pending. On August 22, 2025, the EPA notified Calumet that we were successful in receiving full or partial exemptions on every petition that was filed by the Company through 2024 inclusive. With that decision, the Company’s prior 2019-2024 accrued balance sheet liability of 396 million RINs was reduced to 89 million RINs, of which 57 million are of 2022 and 2023 vintage, and 32 million are 2024. The grant of partial exemption is a new initiative. The Company has applied for review of the partial exemptions for 2022-2024 at Shreveport and 2023-2024 at Montana and believes the correction of scoring errors will result in full exemption. The 2025 petition has not yet been decided by EPA.

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Refer to Note 2 — “Summary of Significant Accounting Policies” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” for additional information.

The RVO is a quantity and cannot be settled financially with EPA. The Company accounts for its current period RVO by multiplying the quantity of RINs shortage (based on actual results) by the period end RINs spot price, which is recorded as a current liability in the consolidated balance sheets and revalued at the end of each subsequent accounting period, which produces non-cash mark-to-market adjustments that are reflected in cost of sales in the consolidated statements of operations (with the exception of RINs for compliance year 2019 related to the San Antonio refinery, which amount is reflected in other operating expense in the consolidated statements of operations for the year ended December 31, 2023). RINs generated by blending may be sold or held to offset future RVO. Any gains or losses from RINs sales are recorded in cost of sales in the consolidated statements of operations.

Our RINs Obligation is measured at the RINs spot prices obtained from an independent pricing service as of each balance sheet date. However, certain vintage RINs are very thinly traded, and the period end spot prices might not be an accurate reflection of the actual amount that we could purchase RINs in the open market in the quantities that would be required to satisfy our RINs volume obligation. Read Note 2 — “Summary of Significant Accounting Policies” for further information on our RINs obligation.

Recent Accounting Pronouncements

For a summary of recently issued and adopted accounting standards applicable to us, read Note 2 — “Summary of Significant Accounting Policies” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements.”

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

We are exposed to market risks from adverse changes in commodity prices, the price of credits needed to comply with governmental programs, interest rates and foreign currency exchange rates. Information relating to quantitative and qualitative disclosures about material market risk is set forth below.

Calumet, Inc. /DE 10-K