Calumet, Inc. /DE (CLMT)

CIK: 0002013745. SIC: 2911 Petroleum Refining. Latest 10-K as of: 2026-02-27.

SIC breadcrumb: Manufacturing > Petroleum Refining And Related Industries > SIC 2911 Petroleum Refining

SEC company page: https://www.sec.gov/edgar/browse/?CIK=2013745. Latest filing source: 0002013745-26-000007.

Selected Fundamentals

Financials

Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-02-27. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0002013745.json. Derived margins, ratios, and free cash flow are computed from the extracted annual SEC facts.

Flow metrics use full-year FY periods from 10-K/10-K/A filings; balance-sheet metrics use FY-end instants. Free cash flow = operating cash flow - capital expenditures. Missing metrics are omitted rather than fabricated.

Ratios

ROE and ROA use period-end equity/assets. Liabilities / equity uses total liabilities divided by stockholders' equity. Current ratio uses current assets divided by current liabilities when both are reported.

Financial Charts

Quarterly

Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-05-08. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0002013745.json.

Flow metrics use discrete quarter-length periods from 10-Q/10-Q/A filings. Q4 revenue and net income are derived only when annual FY and nine-month YTD facts exist for the same fiscal year; derived Q4 values are labeled. EPS Q4 is not derived.

Quarterly Charts

Macro Cross-References

• CPIAUCSL - Consumer Price Index for All Urban Consumers: All Items in U.S. City Average
• UNRATE - Unemployment Rate
• FEDFUNDS - Federal Funds Effective Rate
• CES0500000003 - Average Hourly Earnings of All Employees, Total Private
• DFEDTARU - Federal Funds Target Range - Upper Limit
• DFEDTARL - Federal Funds Target Range - Lower Limit
• DGS3MO - Market Yield on U.S. Treasury Securities at 3-Month Constant Maturity
• DGS2 - Market Yield on U.S. Treasury Securities at 2-Year Constant Maturity
• DGS10 - Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity
• DGS30 - Market Yield on U.S. Treasury Securities at 30-Year Constant Maturity
• T10Y2Y - 10-Year Treasury Constant Maturity Minus 2-Year Treasury Constant Maturity
• CPILFESL - Consumer Price Index for All Urban Consumers: All Items Less Food and Energy
• CPIUFDSL - Consumer Price Index for All Urban Consumers: Food
• CPIENGSL - Consumer Price Index for All Urban Consumers: Energy
• CUSR0000SAH1 - Consumer Price Index for All Urban Consumers: Shelter
• PCEPI - Personal Consumption Expenditures: Chain-type Price Index
• PCEPILFE - Personal Consumption Expenditures Excluding Food and Energy: Chain-type Price Index
• PPIACO - Producer Price Index by Commodity: All Commodities
• T10YIE - 10-Year Breakeven Inflation Rate
• U6RATE - Total Unemployed, Plus All Marginally Attached Workers Plus Total Employed Part Time for Economic Reasons
• PAYEMS - All Employees, Total Nonfarm
• CIVPART - Labor Force Participation Rate
• EMRATIO - Employment-Population Ratio
• UNEMPLOY - Unemployed
• CE16OV - Employment Level
• ICSA - Initial Claims
• JTSJOL - Job Openings: Total Nonfarm
• JTSQUR - Quits: Total Nonfarm
• GDPC1 - Real Gross Domestic Product
• A191RL1Q225SBEA - Real Gross Domestic Product: Percent Change from Preceding Period
• INDPRO - Industrial Production: Total Index
• TCU - Capacity Utilization: Total Index
• HOUST - New Privately-Owned Housing Units Started: Total Units
• PERMIT - New Privately-Owned Housing Units Authorized in Permit-Issuing Places: Total Units
• RSAFS - Advance Retail Sales: Retail Trade
• PCE - Personal Consumption Expenditures
• DSPIC96 - Real Disposable Personal Income
• PSAVERT - Personal Saving Rate
• M2SL - M2
• BOPGSTB - U.S. International Trade in Goods and Services: Balance
• MSPUS - Median Sales Price of Houses Sold for the United States
• HSN1F - New One Family Houses Sold: United States
• RHORUSQ156N - Homeownership Rate in the United States
• TTLCONS - Total Construction Spending: Total Construction in the United States
• RRVRUSQ156N - Rental Vacancy Rate in the United States
• TOTALSL - Total Consumer Credit Owned and Securitized
• REVOLSL - Revolving Consumer Credit Owned and Securitized
• DRCCLACBS - Delinquency Rate on Credit Card Loans, All Commercial Banks
• GDP - Gross Domestic Product
• GPDI - Gross Private Domestic Investment
• GCE - Government Consumption Expenditures and Gross Investment
• PCEC - Personal Consumption Expenditures
• NETEXP - Net Exports of Goods and Services
• GFDEBTN - Federal Debt: Total Public Debt
• GFDEGDQ188S - Federal Debt: Total Public Debt as Percent of Gross Domestic Product
• FYFSD - Federal Surplus or Deficit
• FGRECPT - Federal Government Current Receipts
• FGEXPND - Federal Government: Current Expenditures
• MANEMP - All Employees, Manufacturing
• USCONS - All Employees, Construction
• USTRADE - All Employees, Retail Trade
• USFIRE - All Employees, Financial Activities
• USGOVT - All Employees, Government
• AWHAETP - Average Weekly Hours of All Employees, Total Private
• DGORDER - Manufacturers' New Orders: Durable Goods
• NEWORDER - Manufacturers' New Orders: Nondefense Capital Goods Excluding Aircraft
• BUSINV - Total Business Inventories
• EXPGS - Exports of Goods and Services
• IMPGS - Imports of Goods and Services
• IR - Import Price Index (End Use): All Commodities
• PPIFIS - Producer Price Index by Commodity: Final Demand

Latest quarter (10-Q)

Latest 10-Q source: 0002013745-26-000016.

Extracted structurally from real Item 2 body heading to real Item 3/4 boundary. Published MD&A gate trimmed front/tail over-capture. Confidence: high. Filing date: 2026-05-08. Report date: 2026-03-31.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The historical unaudited condensed consolidated financial statements included in this Quarterly Report reflect all of the assets, liabilities and results of operations of Calumet, Inc. (“Calumet,” the “Company,” “we,” “our,” or “us”). The following discussion analyzes the financial condition and results of operations of the Company for the three months ended March 31, 2026. Stockholders should read the following discussion and analysis of our financial condition and results of operations in conjunction with our 2025 Annual Report and our historical unaudited condensed consolidated financial statements and notes included elsewhere in this Quarterly Report.

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; and Montana/Renewables. For additional information, see Note 10 — “Segments and Related Information” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed 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 located in Great Falls, Montana — renewable fuels and specialty asphalt. At our renewable fuels facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel, renewable hydrogen, renewable natural gas, renewable propane, and renewable naphtha that are distributed into renewable markets in the western half of North America. At our 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.

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 and sold $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 8.125% Senior Notes due 2027 (the “2027 Notes”) in January 2026.

On March 17, 2026, the Issuers issued and sold $150.0 million aggregate principal amount of additional 2031 Notes (the “Additional Notes”) in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act of 1933. The Company used the net proceeds from the offering of the Additional Notes to repay borrowings outstanding under the Company’s revolving credit facility. See Note 6 — “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

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

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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. See Note 6 — “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

Shreveport Supply and Offtake Agreement

On March 30, 2026, the Company entered into the Second Omnibus Amendment Agreement with J. Aron and the other parties thereto, to extend the expiration date of the Shreveport Supply and Offtake Agreement to January 31, 2030. Refer to Note 5 — “Inventory Financing Agreements” for additional information.

Crack Spread Swaps Sales Contracts

In April 2026, the Company entered into additional crack spread swap contracts with a counterparty to reduce our exposure to commodity price risk. These additional swap contracts were for 5,000 bpd in the fourth quarter 2026 and 4,000 bpd during each respective quarter in 2027. As of April 30, 2026, we had the following notional contracts related to outstanding crack spread swap contracts, which are derivative instruments not designated as hedges:

​

​

​

​

​

​

​

​

​

​

​

Avg. Strike Price ($/bbl)

Period of

​

Total Outstanding

​

​

for 2-1-1 Crack Spread Swap

Maturity

  ​ ​ ​

Notional Volumes (bpd)

  ​ ​ ​

​

Based on CBOB

2Q 2026

10,000

$

22.81

3Q 2026

​

10,000

​

$

21.66

4Q 2026

​

15,000

​

$

20.70

1Q 2027

​

10,000

​

$

28.01

2Q 2027

​

10,000

​

$

27.21

3Q 2027

​

10,000

​

$

26.11

4Q 2027

​

10,000

​

$

24.57

​

See Note 7 — “Derivatives” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information related to the Company’s derivatives.

Update Regarding Renewable Volume Obligation

On March 27, 2026, EPA announced a final rule to establish required Renewable Fuel Standard Volumes and percentage standards for 2026 and 2027, which sets the highest renewable fuel volumes in the history of the program. The EPA’s updated Renewable Volume Obligations (“RVOs”) establish total demand of 26.81 billion RINs and 27.02 billion RINs for 2026 and 2027, respectively, providing a historic level of annualized support for the biofuels industry. The 2026 and 2027 volumes include approximately 70% of renewable fuel volumes previously waived through small refinery exemptions (“SREs”) across the 2023–2025 compliance periods. These actions are expected to improve biobased diesel industry margins; improve utilization; and attract currently idled higher-cost biodiesel producers to re-enter the market in order to meet mandated demand. The RVO framework is aligned with a broader national focus on domestic energy security. The EPA also proposed that beginning in 2028, foreign source renewable fuels and feedstocks will receive only half the RFS compliance value of American-made products, materially enhancing the competitive position of domestic producers. Consistent with these developments, 2026 RIN prices continued to recover through April following the RVO announcement. Against this favorable regulatory backdrop, MRL’s strategic location and proximity to domestic customers and suppliers position the company for strong performance in the second half of 2026, continued momentum into 2027, and a sustained long-term competitive advantage.

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First Quarter 2026 Update

Outlook and Trends

We believe the business is well positioned to deliver improved performance, supported by a diversified customer base, a resilient specialty portfolio, and the benefits of multi-year capital investments that continue to enhance operational reliability. In addition, the current strength in fuel cracks is expected to provide a meaningful tailwind to commodity margins. Near-term performance is expected to be influenced by volatility in feedstock costs, which can create temporary margin compression in certain specialty products; however, we expect proactive pricing actions to support margin recovery as these increases are realized. During the first quarter of 2026, operations at our Shreveport facility were temporarily suspended across significant portions of the plant as a precaution to protect our employees and equipment following the discovery of organic chlorides in feedstock tanks, resulting in an estimated loss of approximately 750,000 barrels of production. Following extensive product testing, asset inspections, and repairs, the facility resumed full operations in early April 2026 and is currently processing over 50,000 barrels per day. The Company continues to work with third-party experts to investigate the source of the contamination.

At Montana Renewables, we continue to meet or outperform our operational cost targets prior to the start of our MaxSAF® 150 expansion and turnaround that began in early March, while demonstrating success in monetizing Section 45Z Clean Fuel Production Tax Credits (“CFPCs”). The MaxSAF® 150 expansion and turnaround was successfully completed in approximately 48 days and the facility resumed production in the second quarter of 2026. Our overall enhanced operational performance is a direct result of our focus on operational excellence since we completed commissioning in 2023.

In our Specialties Products and Solutions and Performance Brands segments, we continue to benefit from an attractive specialty product margin environment, although margins were temporarily compressed in the first quarter due to feedstock headwinds. Our fuels and asphalt business was also impacted by the temporary Shreveport production issues, partially offsetting improved commodity margins. Demand for our products in these businesses remained strong 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 to be volatile in the near-term due to the Iran conflict impacting global feedstocks and the Company continues to implement price increases that began in the first quarter of 2026.

In our Montana/Renewables segment, we believe long-term demand for renewable fuel products will continue to grow supported by Federal, State, Provincial and local governmental mandates and incentives that have been enacted or announced in North America and globally. Collectively, these policies focus on domestic fuel security, strategic alignment with the agricultural industry as a source of renewable feedstocks, sustainability initiatives, transportation fuel cleanliness including ongoing reduction in particulates, and expansion of both voluntary and mandatory corporate decarbonization targets, particularly for hard-to-abate sectors including the global aviation industry. We believe that our advantage as a first-mover in sustainable aviation fuels market positions us as a preferred supplier to our potential offtake partners’ SAF strategies. The start-up of our MaxSAF® 150 project allows us to shift our re

[Excerpt truncated for page length; source filing is linked above.]

Latest 10-K MD&A

Extracted structurally from real Item 7 body heading to real Item 7A/8 boundary. Confidence: high. Filing date: 2026-02-27. Report date: 2025-12-31.

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

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. 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.

Refer to Note 2 — “Summary of Significant Accounting Policies” under Part II, Item 8 “Financial Statements — Notes to Consolidated Financial Statements” for further information on the Company’s RINs obligation.

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

58

Table of Contents

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.

59

Table of Contents

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

​

​

60

Table of Contents

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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Table of Contents

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

62

Table of Contents

(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)

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.

​

​

63

Table of Contents

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

64

Table of Contents

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

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.

Debt and Credit Facilities

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

●

$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”);

●

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

●

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

●

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

●

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

●

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

●

$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 arrangement; and

●

$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.

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.

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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:

●

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” 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 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 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.”

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.

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

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.

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.”