UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

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

For the fiscal year ended December 31, 2023

OR

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

Commission file number 000-51734

Calumet Specialty Products Partners, L.P.

(Exact Name of Registrant as Specified in Its Charter)

Delaware	35-1811116
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification Number)
2780 Waterfront Parkway East Drive, Suite 200
Indianapolis, IN	46214
(Address of Principal Executive Offices)	(Zip Code)

(317) 328-5660

(Registrant’s Telephone Number, Including Area Code)

None

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

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

Title of Each Class	Trading symbol(s)	Name of Each Exchange on Which Registered
Common units representing limited partner interests	CLMT	The Nasdaq Stock Market LLC

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

NONE.

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

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

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

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

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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller Reporting Company	☐
		Emerging growth company	☐

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

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

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

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

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

The aggregate market value of the common units held by non-affiliates of the registrant was approximately $1.0 billion on June 30, 2023, based on $15.86 per unit, the closing price of the common units as reported on the Nasdaq Global Select Market on such date.

On February 28, 2024, there were 80,223,093 common units outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

NONE.

EXPLANATORY NOTE

Restatement Background

On February 22, 2024, management of Calumet Specialty Products Partners, L.P. (the “Partnership”) and the Audit and Finance Committee (the “Audit and Finance Committee”) of the Board of Directors of Calumet GP, LLC, the general partner of the Partnership, concluded that the Partnership’s consolidated audited financial statements for the fiscal year ended December 31, 2022 (the “Annual Non-Reliance Period”) included in the Partnership’s Annual Report on Form 10-K for the Annual Non-Reliance Period and the unaudited interim consolidated financial statements for the periods ended March 31, 2023, June 30, 2023, and September 30, 2023 (collectively, the “Interim Non-Reliance Periods” and, together with the Annual Non-Reliance Period, the “Non-Reliance Periods”) included in the Partnership’s Quarterly Reports on Form 10-Q for each of the Interim Non-Reliance Periods, in each case, require restatements and should no longer be relied upon.

As described in the Partnership’s Current Report on Form 8-K filed with the SEC on February 23, 2024, during the preparation of the Partnership’s consolidated financial statements as of and for the year ended December 31, 2023, the Partnership identified an error in the presentation of net income (loss) to partners arising from the misallocation of net loss from Montana Renewables Holdings LLC, a subsidiary of the Partnership (“MRHL”), to noncontrolling interest. The Partnership previously reported its net loss attributable to noncontrolling interest based on the relative ownership interest of the equity holders in MRHL, which was approximately 14% for the noncontrolling interest. The Partnership has subsequently determined that, under applicable accounting standards, no portion of the net loss from MRHL should have been allocated to noncontrolling interest.

Restatement of Previously Issued Consolidated Financial Statements

This Annual Report on Form 10-K for the year ended December 31, 2023 (this “Form 10-K”) includes restated consolidated financial statements as of and for the year ended December 31, 2022 and unaudited interim financial information for the Interim Non-Reliance Periods. In addition to the restatement error described above, the Partnership has corrected certain items that were concluded as immaterial, individually and in the aggregate, to the financial statements for the Non-Reliance Periods.

Control Considerations

See Item 9A, Controls and Procedures, for information related to the material weakness in internal control over financial reporting and the related remedial measures.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

FORM 10-K — 2023 ANNUAL REPORT

Table of Contents

		Page
PART I
Items 1 and 2.	Business and Properties	6
Item 1A.	Risk Factors	30
Item 1B.	Unresolved Staff Comments	58
Item 1C.	Cybersecurity	58
Item 3.	Legal Proceedings	59
Item 4.	Mine Safety Disclosures	59
PART II
Item 5.	Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities	60
Item 6.	[Reserved]	61
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	62
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	85
Item 8.	Financial Statements and Supplementary Data	88
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	151
Item 9A.	Controls and Procedures	151
Item 9B.	Other Information	155
Item 9C.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	155
PART III
Item 10.	Directors, Executive Officers of Our General Partner and Corporate Governance	156
Item 11.	Executive and Director Compensation	162
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters	178
Item 13.	Certain Relationships and Related Transactions and Director Independence	181
Item 14.	Principal Accounting Fees and Services	184
PART IV
Item 15.	Exhibits	185
Item 16.	Form 10-K Summary	191

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FORWARD-LOOKING STATEMENTS

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

References in this Annual Report to “Calumet Specialty Products Partners, L.P.,” “Calumet,” “the Company,” “we,” “our,” “us” or like terms refer to Calumet Specialty Products Partners, L.P. and its subsidiaries. References in this Annual Report to “our general partner” refer to Calumet GP, LLC, the general partner of Calumet Specialty Products Partners, L.P.

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SUMMARY OF RISK FACTORS

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

Risks Related to Our Business

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

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

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

● Decreases in the price of inventory and products may lead to a reduction in the borrowing base under our revolving credit facility and our ability to issue letters of credit or the requirement that we post substantial amounts of cash collateral for derivative instruments.

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

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

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

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

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

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

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

● Our arrangements with J. Aron (as defined herein) and Wells Fargo (as defined herein) expose us to J. Aron and/or Wells Fargo-related credit and performance risk as well as potential refinancing risks.

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

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

● A change of control could result in us facing substantial repayment obligations under our revolving credit facility, our senior notes, our secured hedge agreements, our Supply and Offtake Agreements (as defined below), the MRL revolving credit agreement (as defined below), the Montana Renewables, LLC (“MRL”) financing arrangements with Stonebriar (as defined below), and the MRL term loan credit agreement with I Squared.

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

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

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

● 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.

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

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

Risks Related to the Corporate Conversion

● The Corporate Conversion is subject to conditions, including some conditions that may not be satisfied on a timely basis, if at all. Failure to complete the Corporate Conversion, or significant delays in completing the Corporate Conversion, could negatively affect our business and financial results and the price of our common units or, following the consummation of the Corporate Conversion, future business and financial results and the price of the common stock.

Risks Related to Our Partnership Structure

● We may not have sufficient cash from operations, following the establishment of cash reserves and payment of fees and expenses, including cost reimbursements to our general partner, to enable us to resume paying distributions to our unitholders or restore distributions to previous levels.

● The amount of cash we have available for distribution to unitholders depends primarily on our cash flow and not solely on profitability.

● Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which may permit them to favor their own interests to other unitholders’ detriment.

● The Heritage Group and certain of its affiliates may engage in limited competition with us.

● Our partnership agreement contains provisions that reduce the standards to which our general partner would otherwise be held by state fiduciary duty law.

● Unitholders have limited voting rights and are not entitled to elect our general partner or its directors.

Tax Risks to Common Unitholders

● Our tax treatment depends on our status as a partnership for federal income tax purposes. Our cash available for distribution to unitholders may be substantially reduced if we become subject to entity-level taxation as a result of the Internal Revenue Service (“IRS”) (i) treating us a corporation or (ii) assessing and collecting tax directly from the partnership resulting from or any audit adjustments.

● Our tax treatment or the tax treatment of our unitholders could be subject to potential legislative, judicial, or administrative changes and differing interpretations, possibly applied on a retroactive basis.

● Our unitholders may be required to pay taxes on their share of our income even if they do not receive any distribution from us. A unitholder’s share of our taxable income may be increased as a result of the IRS successfully contesting any of the federal income tax positions we take. Tax gain or loss on the disposition of our common units could be more or less than expected. Unitholders may be subject to limitation on their ability to deduct interest expense incurred by us.

● Tax-exempt entities and foreign persons face unique tax issues from owning our common units that may result in adverse tax consequences to them.

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PART I

Items 1 and 2. Business and Properties

Overview

We manufacture, formulate and market a diversified slate of specialty branded products and renewable fuels to customers across a broad range of consumer-facing and industrial markets. We are headquartered in Indianapolis, Indiana and operate twelve facilities throughout North America. Our business is organized into the following reportable segments: Specialty Products and Solutions; Montana/Renewables; Performance Brands; and Corporate. In our Specialty Products and Solutions segment, we manufacture and market a wide variety of solvents, waxes, customized lubricating oils, white oils, petrolatums, gels, esters, and other products. Our specialty products are sold to domestic and international customers who purchase them primarily as raw material components for consumer-facing and industrial products. In our Performance Brands segment, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our Montana/Renewables segment is comprised of two facilities - renewable fuels and specialty asphalt. At our Montana Renewables facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel (“SAF”), renewable hydrogen, renewable natural gas, renewable propane, and renewable naphtha that are distributed into renewables 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.

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Our Assets

Our primary operating assets consist of:

			Sales Volume for the
			Year Ended December 31,
			2023 in Barrels per
Facility	Location	Year Acquired	Day (“bpd”)	Products
Calumet Packaging	Louisiana	2012	1,068	Specialty products including premium industrial and consumer synthetic lubricants, fuels and solvents
Royal Purple	Texas	2012	335	Specialty products including premium industrial and consumer synthetic lubricants
Missouri	Missouri	2012	212	Specialty products including polyol ester-based synthetic lubricants
Karns City	Pennsylvania	2008	1,486	Specialty white mineral oils, solvents, petrolatums, gelled hydrocarbons, cable fillers and natural petroleum sulfonates
Dickinson	Texas	2008	562	Specialty white mineral oils, compressor lubricants and natural petroleum sulfonates
Cotton Valley	Louisiana	1995	4,743	Specialty solvents used principally in the manufacture of paints, cleaners, automotive products and drilling fluids
Princeton	Louisiana	1990	4,896	Specialty lubricating oils, including process oils, base oils, transformer oils, refrigeration oils, and asphalt
Shreveport	Louisiana	2001	42,400	Specialty lubricating oils and waxes, gasoline, diesel, jet fuel and asphalt
Montana Refining	Montana	2012	13,399	Specialty asphalt, gasoline, diesel, and jet fuel
Montana Renewables	Montana	2021	6,188	Renewable diesel, sustainable aviation fuel, renewable hydrogen, renewable natural gas, renewable propane, and renewable naphtha

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

We also use approximately 2,050 leased railcars primarily to receive and ship crude oil and distribute our specialty and fuel products throughout the U.S. and Canada. In addition, we use approximately 450 leased railcars to source renewable feedstocks and distribute renewable fuels products into the western half of North America. In total, we have approximately 7.0 million barrels of aggregate storage capacity at our facilities and leased storage locations.

Montana Renewables. At our Montana Renewables facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel, renewable hydrogen, renewable natural gas, renewable propane, and renewable naphtha. These renewable fuels are distributed into renewable markets in the western half of North America.

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Business Strategies

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

● Enhance Profitability of Our Existing Assets. We focus on identifying opportunities to improve our asset base, deepening our competitive advantages, and increasing our throughput, profitability, and cash flows. Our highest current priority is streamlining the operations at our Montana Renewables facility and planning for expansion projects at the facility. As part of this project design, we converted the historical Great Falls refinery into two independent facilities: a 15,000 bpd specialty asphalt plant and a 15,000 bpd renewable fuels production facility. At our Montana Renewables facility, we successfully commissioned a renewable hydrogen plant, a feedstock pre-treatment unit, and a sustainable aviation fuel unit in 2023. The feedstock pre-treatment unit is expected to unlock the advantaged price and feedstock optionality we have in Montana and the commissioning of the sustainable aviation fuel unit made Montana Renewables the largest SAF producer in the western hemisphere. Other examples include investments in a polymerized modified asphalt unit at our Great Falls Specialty Asphalt facility in 2022, additional wax blending assets at our Calumet Paralogics, LLC (“Paralogics”) facility in 2021, and the addition of storage capacity to increase sales of our most profitable solvents at our Cotton Valley facility in 2021. In addition, we have undertaken various small expansion and optimization projects in our Performance Brands segment over the past four years, including a new packaging line for 1.0 gallon cans of TruFuel to support growth, a new 2.1 gallon pail TruFuel line to meet the market demand for larger package sizes, and a new quart line in Porter, Texas to recognize efficiencies in packaging Bel-Ray products. We intend to continue increasing the profitability of our existing asset base through various low capital requirement measures which may include investments targeting more efficient logistics, improving the product mix of our processing units, and reducing costs through operational modernizations.

● Maintain Sufficient Levels of Liquidity. We are actively focused on maintaining sufficient liquidity to fund our operations and business strategies. As part of a broader effort to maintain an adequate level of liquidity, the board of directors of our general partner unanimously voted to suspend cash distributions, effective beginning the quarter ended March 31, 2016.

● Concentrate on Positive and Growing Cash Flows. We intend to continue to focus on operating assets and businesses that generate positive and growing cash flows. Approximately 89.0% of our continuing operations gross profit in 2023 was generated by our Specialty Products and Solutions segment, which is characterized by stable customer relationships due to our customers’ requirements for the specialized products we provide. In addition, we manage our exposure to crude oil price fluctuations in this segment by passing on incremental feedstock costs to our specialty products customers. In our Performance Brands segment, which accounted for approximately 18.2% of our continuing operations gross profit in 2023, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our fast-growing portfolio of high-performance brands are characterized by strong customer loyalty and stable cash flows. In our Montana/Renewables segment, which accounted for approximately (7.2)% of our continuing operations gross profit in 2023, we expect growth in cash flows as a result of the commissioning of production units at our Montana Renewables facility. Historically, renewable diesel margins have been both significantly higher and more stable than fuel margins. Further, the remaining Great Falls specialty asphalt facility is expected to produce a larger percentage of its products for local retail markets at lower net freight costs.

● Develop and Expand Our Customer Relationships. Due to the specialized nature of certain of our products, the high cost of replacement and the long lead-time associated with the development and production of many of our specialty products, our customers are incentivized to continue their relationships with us. We believe that we offer a more diversified product slate to our customers than competitors do, and we also offer more technical support and bespoke services. In fiscal year 2023, we sold a range of over 1,900 specialty and fuels products to approximately 2,400 customers. We intend to continue to assist our existing customers in their efforts to expand their product offerings, as well as marketing specialty product formulations and services to new customers. By continuing to service our long-term relationships with our broad base of existing customers and by constantly targeting solutions for new customers, we seek to limit our dependence on any one portion of our customer base.

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● Disciplined Approach to Strategic and Complementary Acquisitions. We do not expect to focus on large acquisitions in the near term. However, should the right opportunity develop, our senior management team is prepared to consider acquiring low-risk assets where we can enhance operations and improve profitability and product lines that will complement and expand our specialty product offerings. For example, in March 2020, we acquired Paralogics, a producer of candle and industrial wax blends, which expanded our presence in the specialty wax blending and packaging market while adding new capabilities into our existing wax value chain. In the future, we intend to continue pursuing prudent, accretive acquisitions that will deepen our long-term competitive advantages. We intend to reduce our leverage over time and maintain a capital structure that facilitates competitive access to the capital markets.

Competitive Strengths

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

● We Have Strong Relationships with a Premier Customer Base. We have long-term relationships with many of our customers and we believe that we will continue to benefit from these relationships. Many of these relationships involve lengthy approval processes or certifications that may make switching to a different supplier difficult. In fiscal year 2023, we sold our products to approximately 2,400 customers, and we are continually seeking to deepen those relationships across our broad and diversified customer base. No single customer accounted for more than 10% of our consolidated sales for any of the three years ended December 31, 2023, 2022 and 2021.

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

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

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

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

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

Potential Acquisition and Divestiture Activities

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

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

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

Partnership Structure and Management

Calumet Specialty Products Partners, L.P. is a Delaware limited partnership formed on September 27, 2005. Our general partner is Calumet GP, LLC, a Delaware limited liability company. As of February 28, 2024, we have 80,223,093 common units and 1,637,206 general partner units outstanding. Our general partner owns a 2% general partner interest in our partnership and all incentive distribution rights and has sole responsibility for conducting our business and managing our operations. For more information about our general partner’s board of directors and executive officers, please read Part III, Item 10 “Directors, Executive Officers of Our General Partner and Corporate Governance.”

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Our Operating Assets and Contractual Arrangements

General

The following table sets forth information about our continuing operations. 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,
	2023	2022	% Change		2022	2021	% Change
	(In bpd)		(In bpd)
Total sales volume (1)	79,805	82,946	(3.8)	%	82,946	79,281	4.6	%
Total feedstock runs (2)	77,200	80,447	(4.0)	%	80,447	75,818	6.1	%
Facility production: (3)
Specialty Products and Solutions:
Lubricating oils	10,358	10,951	(5.4)	%	10,951	9,867	11.0	%
Solvents	7,208	7,100	1.5	%	7,100	6,833	3.9	%
Waxes	1,326	1,452	(8.7)	%	1,452	1,335	8.8	%
Fuels, asphalt and other by-products	38,845	40,845	(4.9)	%	40,845	27,869	46.6	%
Total Specialty Products and Solutions	57,737	60,348	(4.3)	%	60,348	45,904	31.5	%
Montana/Renewables:
Gasoline	3,898	3,409	14.3	%	3,409	4,907	(30.5)	%
Diesel	2,941	6,449	(54.4)	%	6,449	9,711	(33.6)	%
Jet fuel	449	820	(45.2)	%	820	901	(9.0)	%
Asphalt, heavy fuel oils and other	4,483	6,942	(35.4)	%	6,942	10,379	(33.1)	%
Renewable fuels	6,314	—	100.0	%	—	—	100.0	%
Total Montana/Renewables	18,085	17,620	2.6	%	17,620	25,898	(32.0)	%
Performance Brands	1,474	1,434	2.8	%	1,434	1,304	10.0	%
Total facility production (3)	77,296	79,402	(2.7)	%	79,402	73,106	8.6	%

(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.

(2) Total feedstock runs represent the barrels per day of crude oil and other feedstocks processed at our facilities and at certain third-party facilities pursuant to supply and/or processing agreements.

(3) The difference between total facility production and total feedstock runs is primarily a result of the time lag between the input of feedstocks and production of finished products and volume loss.

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The following table sets forth information about our sales of principal products by segment:

	Year Ended December 31,
	2023				2022				2021
	(In millions)		% of Sales		(In millions)		% of Sales		(In millions)		% of Sales
Specialty Products and Solutions:
Lubricating oils	$	763.8	18.3	%	$	913.7	19.5	%	$	658.7	20.9	%
Solvents		398.5	9.5	%		434.9	9.3	%		303.7	9.7	%
Waxes		163.9	3.9	%		189.3	4.0	%		151.7	4.8	%
Fuels, asphalt and other by-products		1,550.7	37.1	%		1,970.1	42.0	%		997.3	31.7	%
Total	$	2,876.9	68.8	%	$	3,508.0	74.8	%	$	2,111.4	67.1	%
Montana/Renewables:
Gasoline	$	167.2	4.0	%	$	188.1	4.0	%	$	188.3	6.0	%
Diesel		144.8	3.5	%		391.8	8.4	%		324.9	10.3	%
Jet fuel		20.5	0.5	%		41.8	0.9	%		27.5	0.9	%
Asphalt, heavy fuel oils and other		148.1	3.5	%		253.2	5.4	%		243.0	7.7	%
Renewable fuels		513.2	12.3	%		—	—	%		—	—	%
Total	$	993.8	23.8	%	$	874.9	18.7	%	$	783.7	24.9	%
Performance Brands	$	310.3	7.4	%	$	303.4	6.5	%	$	252.9	8.0	%
Consolidated sales	$	4,181.0	100.0	%	$	4,686.3	100.0	%	$	3,148.0	100.0	%

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

Northwest Louisiana Integrated Specialty Complex

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

Shreveport Facility

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

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

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

	Shreveport Facility
	Year Ended December 31,
	2023	2022	2021
	(In bpd)
Crude oil throughput capacity	60,000	60,000	60,000
Total feedstock runs (1) (2)	38,248	42,453	29,971
Total facility production (2) (3)	40,677	45,525	31,835

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

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

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

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

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

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

Cotton Valley Facility

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

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

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

	Cotton Valley Facility
	Year Ended December 31,
	2023	2022	2021
	(In bpd)
Crude oil throughput capacity	13,600	13,600	13,600
Total feedstock runs (1) (2)	9,125	8,975	8,349
Total facility production (2) (3)	5,520	5,317	4,698

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

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

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

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

The Cotton Valley facility receives crude oil via tank truck. The Cotton Valley facility’s feedstock is primarily low sulfur and paraffinic crude oil originating from north Louisiana and is purchased from various marketers and gatherers. In addition, the Cotton Valley facility receives interplant feedstocks for solvent production from the Shreveport facility. The Cotton Valley facility ships finished products by both truck and railcar service.

Princeton Facility

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

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

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

	Princeton Facility
	Year Ended December 31,
	2023	2022	2021
	(In bpd)
Crude oil throughput capacity	10,000	10,000	10,000
Total feedstock runs (1)	7,724	7,259	7,266
Total facility production (1) (2)	7,787	5,660	4,881

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

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

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

The Princeton facility receives crude oil via tank truck, railcar and the Plains pipeline system. Its crude oil supply primarily originates from east Texas, south Texas and north Louisiana, purchased directly from third-party suppliers under month-to-month evergreen supply contracts and on the spot market. The Princeton facility ships its finished products throughout the U.S. via truck and railcar service.

Great Falls Specialty Asphalt Facility

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

The Great Falls specialty asphalt facility consists of 15 major processing units including hydrotreating, catalytic reforming, hydrocracking, fluid catalytic cracking and alkylation units, approximately 1.1 million barrels of storage capacity in 75 tanks and related loading and unloading facilities and utilities.

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

	Great Falls Specialty Asphalt Facility
	Year Ended December 31,
	2023	2022	2021
	(In bpd)
Crude oil throughput capacity	15,000	15,000	30,000
Total feedstock runs (1) (2)	11,982	17,599	25,614
Total facility production (2)	11,772	17,619	25,897

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

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

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

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

In the fourth quarter of 2022, we completed the reconfiguration of our 30,000 bpd Great Falls specialty asphalt facility into two unrelated facilities, including a 15,000 bpd specialty asphalt facility and a 15,000 bpd renewable fuels facility. The specialty asphalt facility capitalizes on local access to cost-advantaged Canadian conventional crude oil, while producing additional fuels and refined products for delivery into the regional market while meeting EPA requirements for gasoline and diesel product sulfur limits and reducing air emissions. The renewable fuels facility is described below.

Great Falls Renewable Fuels Facility (“Montana Renewables”)

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

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

Missouri Facility

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

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

Calumet Packaging

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

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Royal Purple

The Royal Purple facility (“Royal Purple”), located on a 20 acre site in Porter, Texas, develops, blends and packages high performance synthetic lubricants and fluid additive products for use in industrial, commercial and automotive applications. The Royal Purple facility’s processing capability includes 10 in-house packaging and production lines. Outsourced packaging services for specific products are also fulfilled. The facility has approximately 30,500 barrels of storage capacity in 91 tanks and related loading and unloading facilities. The facility receives its base oil feedstocks and additives by truck under supply agreements or spot agreements with various suppliers.

Karns City and Dickinson Facilities and Other Processing Agreements

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

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

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

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

	Combined Karns City, Dickinson and Other Facilities
	Year Ended December 31,
	2023	2022	2021
	(in bpd)
Feedstock throughput capacity (1)	11,300	11,300	11,300
Total feedstock runs (2) (3)	3,396	3,482	4,368
Total production (3)	3,419	3,582	4,269

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

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

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

Other Logistics Assets

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

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

We use approximately 2,050 railcars leased from various lessors. This fleet of railcars enables us to receive and ship crude oil and distribute various specialty products and fuel products throughout the U.S. and Canada to and from each of our facilities. In addition, we use approximately 450 leased railcars to source renewable feedstocks and distribute renewable fuels products into the western half of North America.

Our Crude Oil and Feedstock Supply

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

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

In 2023, BP Products North America Inc. (“BP”) supplied us with approximately 71.7% of our total crude oil supply under term contracts and month-to-month evergreen crude oil supply contracts. In 2023, Macquarie Energy Canada LTD. (“Macquarie”) supplied us with approximately 18.5% of our total crude oil supply under a crude oil supply agreement. Each of our refineries is dependent on one or more key suppliers and the loss of any of these suppliers would adversely affect our financial results to the extent we were unable to find another supplier of this substantial amount of crude oil.

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

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

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

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

Our cost to acquire crude oil and feedstocks and the prices for which we ultimately can sell refined products depend on a number of factors beyond our control, including regional and global supply of and demand for crude oil, other feedstocks and specialty and fuel products. These, in turn, are dependent upon, among other things, the availability of imports, overall economic conditions, production levels of domestic and foreign suppliers, U.S. relationships with foreign governments, political affairs and the extent of governmental regulation. We have historically been able to pass on the

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costs associated with increased crude oil and feedstock prices to our specialty products customers, although the increase in selling prices for specialty products typically lags the rising cost of crude oil. From time to time, we use a hedging program to manage a portion of our commodity price risk.

Our Products, Markets and Customers

Products

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

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

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

Lubricating Oils	Solvents	Waxes	Packaged and Synthetic Specialty Products	Fuels & Fuel Related Products	Renewable Products
19%	10%	4%	8%	47%	12%
●  Hydraulic oils ●  Passenger car motor oils ●  Railroad engine oils ●  Cutting oils ●  Compressor oils ●  Metalworking fluids ●  Transformer oils ●  Rubber process oils ●  Industrial lubricants ●  Gear oils ●  Grease ●  Automatic transmission fluid ●  Animal feed dedusting ●  Baby oils ●  Bakery pan oils ●  Catalyst carriers ●  Gelatin capsule lubricants ●  Sunscreen	●  Waterless hand cleaners ●  Alkyd resin diluents ●  Automotive products ●  Calibration fluids ●  Charcoal lighter fluids ●  Chemical processing ●  Drilling fluids ●  Printing inks ●  Water treatment ●  Paint and coatings ●  Stains	●  Paraffin waxes ●  FDA compliant products ●  Candles ● Adhesives ●  Crayons ●  Floor care ●  PVC ●  Paint strippers ●  Skin & hair care ●  Timber treatment ●  Waterproofing ●  Pharmaceuticals ●  Cosmetics	●  Refrigeration compressor oils ●  Positive displacement and roto-dynamic compressor oils ●  Commercial and military jet engine oil ●  Lubricating greases ●  Gear oils ●  Aviation hydraulic oils ●  High performance small engine fuels ●  Two cycle and four stroke engine oils ●  High performance automotive engine oils ●  High performance industrial lubricants ●  High temperature chain lubricants ●  Food contact grade lubricants ●  Charcoal lighter fluids and other solvents ●  Engine treatment additives	●  Gasoline ●  Diesel ●  Jet fuel ●  Marine fuel ●  Ethanol free fuels ●  Fluid catalytic cracking feedstock ●  Asphalt vacuum residuals ●  Mixed butanes ●  Roofing flux ●  Paving asphalt ●  Heavy fuel oils	●  Renewable hydrogen ●  Renewable natural gas ●  Renewable propane ●  Renewable naphtha ●  Renewable kerosene/sustainable aviation fuel ●  Renewable diesel

(1) Based on the percentage of total sales for the year ended December 31, 2023. Except for the listed fuel products, renewable products and certain packaged and synthetic specialty products, we do not produce any of these end-use products.

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Marketing

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

Markets

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

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

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

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

We have the capability to ship our specialty products worldwide. In the U.S., we ship our specialty products via railcars, trucks and barges. We use our fleet of leased railcars to ship our specialty products and a majority of our specialty products sales are shipped in trucks owned and operated by several different third-party carriers. For international shipments, which accounted for less than 10% of our consolidated sales in 2023, we ship via railcars and trucks to several ports where the product is loaded onto vessels for shipment to customers abroad.

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

Renewable Fuel Products. The renewable fuel products market represents a small portion of the overall petroleum refining industry in the U.S. MRL is a leading independent producer of renewable transportation fuels in North America and the largest SAF producer in the western hemisphere. The renewable fuels market is in the rapid-growth phase of its life cycle, highlighted by renewable diesel demand growing at an average annualized rate of 96.3% over the past three years, and SAF demand quadrupling in the past year. The U.S. government’s SAF Grand Challenge calls for SAF growth from 4.5 million gallons in 2021 to 3.0 billion gallons annually by 2030. We believe we are well positioned to benefit from these trends.

Gulf Coast Market (PADD 3)

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

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

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

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

Northwest Market (PADD 4)

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

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

Customers

Specialty Products. We have a diverse customer base for our specialty products. In fiscal year 2023, we sold our specialty products to approximately 2,200 customers. Many of our customers are long-term customers who use our products in specialty applications, after an approval process ranging from six months to two years.

Fuel Products. We have a diverse customer base for our fuel products. In fiscal year 2023, we sold our fuel products to approximately 200 customers. Our diverse customer base includes wholesale distributors and retail chains. We are able to sell the majority of the fuel products we produce at the Shreveport facility to the local markets of Louisiana, Texas and Arkansas. We also have the ability to ship additional fuel products from the Shreveport facility to the Midwest region through the TEPPCO pipeline. The majority of our fuel products produced at our Great Falls specialty asphalt facility are sold to local markets in Montana and Idaho as well as in Canada. The renewable fuel products produced at our Montana Renewables facility are distributed into renewable markets in the western half of North America.

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

During the years ended December 31, 2023, 2022 and 2021, we had no customer that represented 10% or greater of consolidated sales.

Competition

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

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

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

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

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

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

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

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

Renewable Fuel Products. Our primary competitor in producing renewable fuel products in the local markets in which we operate is Chevron Corporation.

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

Governmental Regulation

From time to time, we are a party to certain claims and litigation incidental to our business, including claims made by various taxation and regulatory authorities, such as the IRS, the EPA and the U.S. Occupational Safety and Health Administration (“OSHA”), as well as various state environmental regulatory bodies and state and local departments of revenue, as the result of audits or reviews of our business.

Environmental and Occupational Health and Safety Matters

Environmental

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

Moreover, certain of these laws impose joint and several liability and strict liability for costs required to remediate and restore sites where petroleum hydrocarbons, wastes or other materials have been disposed of or released and areas where any such contamination has come to be located. In addition, new environmental and worker safety laws and

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regulations, amendment of existing laws and regulations, reinterpretation of legal requirements, increased governmental enforcement or other developments could significantly increase our operational or compliance expenditures, including as discussed below in more detail.

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

Great Falls Refinery

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

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

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

Air Emissions

Our operations are subject to the federal Clean Air Act, as amended (“CAA”), and comparable state and local laws. Amendments made to the CAA in 1990 require most industrial operations in the U.S. to incur capital expenditures to meet the air emission control standards that are developed and implemented by the EPA and state environmental agencies. Under the CAA, facilities that emit regulated air pollutants are subject to stringent regulations, including requirements to install various levels of control technology on sources of pollutants. In addition, in recent years, the petroleum refining sector has become subject to stringent federal regulations that impose maximum achievable control technology (“MACT”) on refinery equipment emitting certain listed hazardous air pollutants. Some of our facilities have been included within the categories of sources regulated by MACT rules. Our refining and terminal operations that emit regulated air pollutants are also subject to air emissions permitting requirements that incorporate stringent control technology requirements for which we may incur significant capital expenditures. Any renewal of those air emissions permits or a need to modify existing or obtain new air emissions permits has the potential to delay the development of our projects. We can provide no assurance that future compliance with existing or any new laws, regulations or permit requirements will not have a material adverse effect on our business, financial position or results of operations. For example, in 2015, the EPA issued a final rule under

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the CAA making the National Ambient Air Quality Standard (“NAAQS”) for ground-level ozone more stringent. Since that time, the EPA has issued area designations with respect to ground-level ozone and final requirements that apply to state, local and tribal air agencies for implementing the 2015 NAAQS for ground-level ozone. States are expected to implement more stringent requirements as a result of this new final rule, which could apply to our operations. EPA retained the 2015 standards for ground-level ozone after a review completed in 2020. In 2021, EPA announced that it would reconsider this standard, and in August 2023, EPA announced it would begin an entirely new review of the NAAQS for ground-level ozone. Also, in 2015, the EPA published a final rule that amended three refinery standards already in effect, imposing additional or, in some cases, new emission control requirements on subject refineries. The final rule requires, among other things, the monitoring of air concentrations of benzene around the refinery fence line perimeter and submittal of the fence line monitoring data to the EPA on a quarterly basis; upgraded emissions controls for storage tanks, including controls for smaller capacity storage vessels and storage vessels storing materials with lower vapor pressures than previously regulated; enhanced performance requirements for flares including the use of a minimum of three pollution prevention measures, continuous monitoring of flares and pressure release devices and analysis and remedy of flare release events; and compliance with emissions standards for delayed coking units. These final rules and any other future air emissions rulemakings could impact us by requiring installation of new emission controls on some of our equipment, resulting in longer permitting timelines, and significantly increasing our capital expenditures and operating costs, which could adversely impact our business.

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

In 2014, the EPA published more stringent sulfur standards, referred to as “Tier 3 Standards,” including requiring that motor gasoline will not contain more than 10 ppm of sulfur on an annual average basis by January 1, 2017, except in those instances where refineries received a “small refinery” exemption, in which event the deadline was extended to January 1, 2020. Our Shreveport and Great Falls facilities are fully compliant with the 10 ppm sulfur standard with respect to produced gasoline. In addition, we are required to meet the Mobile Source Air Toxics (“MSAT”) II Standards adopted by the EPA to reduce the benzene content of motor gasoline produced at our facilities and have completed capital projects at our Shreveport and Great Falls facilities to comply with those fuel quality requirements.

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

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Climate Change

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

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

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

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

Hazardous Substances and Wastes

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

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

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

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

Water Discharges

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

The primary federal law for oil spill liability is the Oil Pollution Act of 1990, as amended (“OPA”), which addresses three principal areas of oil pollution — prevention, containment and cleanup. The OPA applies to vessels, offshore facilities and onshore facilities, including refineries, terminals and associated facilities that may affect waters of the U.S. Under the OPA, responsible parties, including owners and operators of onshore facilities, may be subject to oil cleanup costs and natural resource damages as well as a variety of public and private damages from oil spills. Historically, our past environmental compliance costs under the existing requirements of the OPA have not had a material adverse effect on our results of operations but this law and its implementing regulations are subject to change and there can be no assurance that such future costs will not be material.

Occupational Health and Safety

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

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result in additional capital expenditures or operating expenses, as well as civil penalties and, in the event of a serious injury or fatality, criminal charges.

Other Environmental and Maintenance Items

We perform preventive and normal maintenance on most, if not all, of our refining and terminal assets and make repairs and replacements when necessary or appropriate. We also conduct inspections of these assets as required by law or regulation.

Insurance

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

Seasonality

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

Properties

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

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

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

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

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

Intellectual Property

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

Office Facilities

In addition to our principal properties discussed above, as of December 31, 2023, we were a party to a number of cancelable and noncancelable leases for certain properties, including our corporate headquarters in Indianapolis, Indiana. The corporate headquarters lease is for 58,501 square feet of office space. The lease term expires in August 2024. Please read Note 4 — “Leases” in Part II, Item 8 “Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements” of this Annual Report for additional information regarding our leases.

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

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Human Capital Management

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

As of February 28, 2024, our general partner employed approximately 1,580 people who provide direct support to our operations. Of these employees, approximately 600 are covered by collective bargaining agreements.

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

Facility	Union	Expiration Date
Cotton Valley	International Union of Operating Engineers	November 19, 2026
Princeton	International Union of Operating Engineers	August 20, 2024
Dickinson	International Union of Operating Engineers	December 12, 2024
Shreveport	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	April 30, 2026
Missouri	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	April 30, 2025
Karns City	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	January 31, 2027
Great Falls	United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union	July 31, 2026

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

Compensation and Benefits

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

Workforce Health and Safety

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

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

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

Diversity, Inclusion and Workplace Culture

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

Address, Internet Website and Availability of Public Filings

Our principal executive offices are located at 2780 Waterfront Parkway East Drive, Indianapolis, Indiana, 46214 and our telephone number is (317) 328-5660. Our website is located at www.calumet.com.

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

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

Item 1A. Risk Factors

An investment in our common units involves a significant degree of risk. Before you invest in our common units, you should carefully consider the risk factors discussed or referenced below. If any of the risks discussed below were actually to occur, our business, financial position or results of operations could be materially adversely affected.

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Risks Related to our Business

Results of Operations and Financial Condition

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

Such macroeconomic factors include:

● Reduction in the demand for, and the marketability of, our specialty products due to governmental regulations, including travel bans and restrictions, quarantines, shelter in place orders, and shutdowns;

● increased volatility in product margins;

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

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

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

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

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

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

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

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

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

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

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

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

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$50.05 per barrel to a low of $13.98 per barrel during 2023 and averaged $31.64 per barrel during 2023 compared to an average of $39.96 in 2022.

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

Our specialty product margins are influenced by the price of our feedstocks, many of which are commodities. If feedstock prices increase, our margins would fall unless we are able to pass through these price increases to our customers. For example, during fiscal year 2022, higher material and feedstock costs adversely impacted our margins for our Performance Brands segment.

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

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

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

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

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

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

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are required to post substantial amounts of cash collateral to our hedging counterparties, our liquidity, financial condition and our ability to make payments on our debt obligations could be materially and adversely affected. Please read Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Debt and Credit Facilities” for additional information.

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

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

The unavailability of any of these third-party pipelines for the transportation of crude oil or our refined fuel products, because of acts of God, accidents, earthquakes or hurricanes, government regulation, terrorism or other third-party events, could lead to disputes or li