UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q


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

FOR THE QUARTERLY PERIOD ENDED ~~September~~March 3031, ~~2023~~2024


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

FOR THE TRANSITION PERIOD FROM TO

Commission File Number: 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

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

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

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

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

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

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

On ~~November~~May 910, ~~2023~~2024, there were 7980,~~967~~388,~~363~~555 common units outstanding.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

QUARTERLY REPORT

For the Three ~~and Nine~~ Months Ended ~~September~~March 3031, ~~2023~~2024

Table of Contents


	Page
Part I
Item 1. Financial Statements
Condensed Consolidated Balance Sheets	4
Unaudited Condensed Consolidated Statements of Operations	5
Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)	6
Unaudited Condensed Consolidated Statements of Partners’ Capital (Deficit)	7
Unaudited Condensed Consolidated Statements of Cash Flows	98
Notes to Unaudited Condensed Consolidated Financial Statements	109
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	4036
Item 3. Quantitative and Qualitative Disclosures About Market Risk	6151
Item 4. Controls and Procedures	6354

Part II
Item 1. Legal Proceedings	6455
Item 1A. Risk Factors	6455
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	6455
Item 3. Defaults Upon Senior Securities	6455
Item 4. Mine Safety Disclosures	6455
Item 5. Other Information	6555
Item 6. Exhibits	6656

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FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this “Quarterly 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) ~~the~~ effect, impact, potential duration or other implications of supply chain disruptions, global energy shortages and the ongoing novel coronavirus (“COVID-19”) pandemic on our business and operations; (ii) demand for finished products in markets we serve; (~~iii~~ii) estimated capital expenditures as a result of required audits or required operational changes or other environmental and regulatory liabilities; (iviii) 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; (viv) 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; (viv) our ability to meet our financial commitments, debt service obligations, debt instrument covenants, contingencies and anticipated capital expenditures; (~~vii~~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; (~~viii~~vii) our access to inventory financing under our supply and offtake agreements; (ixviii) 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) the expected benefits of the ~~Corporate~~Conversion ~~Reorganization~~ (as defined herein) to us and our unitholders; and (xiii) the anticipated completion of the ~~Corporate~~Conversion ~~Reorganization~~ and the timing thereof, as well as other matters discussed in this Quarterly 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. Factors that could cause our actual results to differ from those in the forward-looking statements include those described in Part I, Item 1A “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2022~~2023 (“~~2022~~2023 Annual Report”). Certain public statements made by us and our representatives on the date hereof may also contain forward-looking statements, which are qualified in their entirety by the cautionary statements contained in this paragraph. 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 Quarterly 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 Quarterly Report to “our general partner” refer to Calumet GP, LLC, the general partner of Calumet Specialty Products Partners, L.P.

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PART I

Item 1. Financial Statements

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS


	~~September~~March 3031, ~~2023~~2024		December 31, ~~2022~~2023
	(Unaudited)
	(In millions, except unit data)
ASSETS
Current assets:
Cash and cash equivalents	$	1323.79	$	357.29
Accounts receivable, net:
Trade, less allowance for credit losses of $1.3 million and $1.3 million, respectively		285.0		245.7
Trade, less allowance for credit losses of $1.4 million and $1.2 million, respectively		289.4		252.4
Other		6249.86		2233.38
		~~347~~339.80		~~268~~286.02
Inventories		~~447~~403.71		~~498~~439.04
Derivative assets		5.25		—9.6
Prepaid expenses and other current assets		4940.02		1951.26
Total current assets		~~863~~811.47		~~820~~794.47
Property, plant and equipment, net		1,~~526~~486.90		1,~~482~~506.03
Other noncurrent assets, net		~~414~~433.59		~~439~~450.43
Total assets	$	2,~~804~~731.86	$	2,~~741~~751.83
LIABILITIES AND PARTNERS’ CAPITAL (DEFICIT)
Current liabilities:
Accounts payable	$	~~342~~321.1	$	~~442~~322.40
Accrued interest payable		41.23		3448.67
Accrued salaries, wages and benefits		8268.94		9387.01
Obligations under inventory financing agreements		~~237~~55.96		~~221~~190.84
Current portion of RINs obligation		~~326~~212.37		~~399~~277.3
Derivative liabilities		—		26.5
Other current liabilities		99.0		131.5
Other current liabilities		85.2		114.5
Current portion of long-term debt		26.3		55.7
Current portion of long-term debt		204.6		20.0
Total current liabilities		824.4		1,112.7
Total current liabilities		1,320.2		1,352.1
Other long-term liabilities		135.7		53.6
Other long-term liabilities		57.5		60.2
Long-term debt, less current portion		2,055.6		1,829.7
Long-term RINs obligation, less current portion		16.5		77.5
Total liabilities	$	3,015.7	$	2,996.0
Long-term debt, less current portion		1,608.2		1,539.7
Commitments and contingencies
Total liabilities	$	3,002.4	$	3,029.5
Redeemable noncontrolling interest	$	245.6	$	245.6
Commitments and contingencies
Partners’ capital (deficit):
Redeemable noncontrolling interest	$	250.0	$	250.0
Limited partners’ interest (80,223,093 units and 79,967,363 units, issued and outstanding at March 31, 2024 and December 31, 2023, respectively)	$	(523.1)	$	(484.4)
Partners’ capital (deficit):
General partner’s interest		0.5		1.3
Limited partners’ interest (79,964,002 units and 79,189,583 units, issued and outstanding at September 30, 2023 and December 31, 2022, respectively)	$	(442.3)	$	(529.9)
Accumulated other comprehensive loss		(7.1)		(7.2)
General partner’s interest		2.8		0.5
Total partners’ capital (deficit)		(529.7)		(490.3)
Accumulated other comprehensive loss		(8.1)		(8.3)
Total liabilities and partners’ capital (deficit)	$	2,731.6	$	2,751.3
Total partners’ capital (deficit)		(447.6)		(537.7)
Total liabilities and partners’ capital (deficit)	$	2,804.8	$	2,741.8

See accompanying notes to unaudited condensed consolidated financial statements.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


	Three Months Ended March 31,	~~Three Months Ended September 30,~~					~~Nine Months Ended September 30,~~
	2024	~~2023~~		2023	~~2022~~		~~2023~~		~~2022~~
	(In millions, except unit and per unit data)	~~(In millions, except unit and per unit data)~~
Sales		$	1,149.4		$	1,165.0	$	3,204.1	$	3,686.9
					(As Restated)
Cost of sales			887.8			1,025.7		2,774.4		3,371.0
Sales	$	1,005.8		$	1,037.3
Gross profit			261.6			139.3		429.7		315.9
Cost of sales		927.3			940.7
Operating costs and expenses:
Gross profit		78.5			96.6
Selling			12.4			11.6		41.4		40.4
Operating costs and expenses:
General and administrative			40.2			43.3		104.5		98.4
Selling		13.7			13.5
Other operating (income) expense			(4.1)			2.5		4.1		16.8
General and administrative		23.3			37.1
Operating income			213.1			81.9		279.7		160.3
Other operating expense		5.2			3.0

Operating income		36.3			43.0
Other income (expense):

Interest expense			(58.7)			(41.8)		(163.7)		(136.0)
Other income (expense):
Debt extinguishment costs			(0.3)			(40.4)		(5.5)		(41.4)
Interest expense		(60.8)			(49.2)
Gain (loss) on derivative instruments		(16.9)	~~(54.3)~~		25.5	~~16.5~~		~~(14.5)~~		~~(73.2)~~
Other income (expense)			0.6			(0.1)		0.1		(3.1)
Other expense		—			(0.2)
Total other expense		(77.7)	~~(112.7)~~		(23.9)	~~(65.8)~~		~~(183.6)~~		~~(253.7)~~
Net income (loss) before income taxes		(41.4)	~~100.4~~		19.1	~~16.1~~		~~96.1~~		~~(93.4)~~
Income tax expense		0.2	~~0.5~~		0.5	~~1.5~~		~~1.4~~		~~2.8~~
Net income (loss)	$	$(41.6)	~~99.9~~	$	$18.6	~~14.6~~	$	~~94.7~~	$	~~(96.2)~~
Net loss attributable to noncontrolling interest			(3.1)			(1.1)		(18.5)		(1.1)
Allocation of net income (loss) to partners:
Net income (loss) attributable to partners	$	$(41.6)	~~103.0~~	$	$18.6	~~15.7~~	$	~~113.2~~	$	~~(95.1)~~
Allocation of net income (loss) to partners:
Less:
Net income (loss) attributable to partners		$	103.0		$	15.7	$	113.2	$	(95.1)
General partners’ interest in net income (loss)		(0.8)			0.4
Less:
Net income (loss) available to limited partners	$	(40.8)		$	18.2
General partners’ interest in net income (loss)			2.1			0.3		2.3		(1.9)
Weighted average limited partner units outstanding:
Non-vested share based payments			0.1			0.2		0.1		—
Basic		80,352,403			79,830,671
Net income (loss) available to limited partners		$	100.8		$	15.2	$	110.8	$	(93.2)
Diluted		80,352,403			79,939,985
Weighted average limited partner units outstanding:
Limited partners’ interest basic net income (loss) per unit:
Basic			80,172,810			79,384,878		80,046,930		79,277,719
Limited partners’ interest	$	(0.51)		$	0.23
Diluted			80,277,483			80,461,600		80,148,519		79,277,719
Limited partners’ interest diluted net income (loss) per unit:
Limited partners’ interest basic net income (loss) per unit:
Limited partners’ interest	$	(0.51)		$	0.23
Limited partners’ interest		$	1.26		$	0.19	$	1.38	$	(1.18)
Limited partners’ interest diluted net income (loss) per unit:
Limited partners’ interest		$	1.26		$	0.19	$	1.38	$	(1.18)

See accompanying notes to unaudited condensed consolidated financial statements.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)


	Three Months Ended ~~September~~March 3031,				~~Nine Months Ended September 30,~~
	~~2023~~2024		~~2022~~2023		~~2023~~		~~2022~~
	(In millions)
Net income (loss)	$	99.9	$	14.6	$	94.7	$	(96.2)
				(As Restated)
Other comprehensive income:
Net income (loss)	$	(41.6)	$	18.6
Defined benefit pension and retiree health benefit plans		0.1		0.1		0.2		0.2
Other comprehensive income:
Total other comprehensive income		0.1		0.1		0.2		0.2
Defined benefit pension and retiree health benefit plans		0.1		—
Comprehensive income (loss) attributable to partners’ capital (deficit)	$	100.0	$	14.7	$	94.9	$	(96.0)
Total other comprehensive income		0.1		—
Less: Comprehensive loss attributable to noncontrolling interest		(3.1)		(1.1)		(18.5)		(1.1)
Comprehensive income (loss) attributable to partners’ capital (deficit)	$	(41.5)	$	18.6
Comprehensive income (loss) attributable to partners’ capital (deficit)	$	103.1	$	15.8	$	113.4	$	(94.9)

See accompanying notes to unaudited condensed consolidated financial statements.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (DEFICIT)


	Accumulated
	Other		Partners’ Capital (Deficit)
	Comprehensive		General		Limited
	Loss		Partner		Partners		Total
		(In millions)
Balance at June 30, 2023	$	(8.2)	$	0.7	$	(540.3)	$	(547.8)
Balance at December 31, 2023	$	(7.2)	$	1.3	$	(484.4)	$	(490.3)
Other comprehensive income		0.1		—		—		0.1
Net income attributable to partners		—		2.1		100.9		103.0
Net loss attributable to partners		—		(0.8)		(40.8)		(41.6)
Amortization of phantom units		—		—		0.2		0.2
Settlement of tax withholdings on equity-based incentive compensation		—		—		(3.5)		(3.5)
Adjustment to ASC 480 redemption value		—		—		(3.1)		(3.1)
Settlement of phantom units		—		—		5.6		5.6
Balance at September 30, 2023	$	(8.1)	$	2.8	$	(442.3)	$	(447.6)
Balance at March 31, 2024	$	(7.1)	$	0.5	$	(523.1)	$	(529.7)


	Accumulated
	Other		Partners’ Capital (Deficit)
	Comprehensive		General		Limited
	Loss		Partner		Partners		Total
	(In millions)	~~(In millions)~~
Balance at December 31, 2022	$	(8.3)	$	0.5	$	(529.9)	$	(537.7)
Balance at December 31, 2022 (As Restated)	$	(8.3)	$	0.3	$	(525.3)	$	(533.3)
Other comprehensive income		0.2		—		—		0.2
Net income attributable to partners		—		0.4		18.2		18.6
Net income attributable to partners		—		2.3		110.9		113.2
Settlement of tax withholdings on equity-based incentive compensation		—		—		(7.9)		(7.9)
Settlement of tax withholdings on equity-based incentive compensation		—		—		(9.6)		(9.6)
Settlement of phantom units		—		—		(1.0)		(1.0)
Settlement of phantom units		—		—		4.2		4.2
Amortization of phantom units		—		—		0.3		0.3
Amortization of phantom units		—		—		0.6		0.6
Balance at March 31, 2023 (As Restated)	$	(8.3)	$	0.7	$	(515.7)	$	(523.3)
Adjustment to ASC 480 redemption value		—		—		(18.5)		(18.5)
Balance at September 30, 2023	$	(8.1)	$	2.8	$	(442.3)	$	(447.6)


	Accumulated
	Other		Partners’ Capital (Deficit)
	Comprehensive		General		Limited
	Loss		Partner		Partners		Total
	(In millions)
Balance at June 30, 2022	$	(10.0)	$	1.6	$	(469.2)	$	(477.6)
Other comprehensive income		0.1		—		—		0.1
Net income attributable to partners		—		0.3		15.4		15.7
Settlement of phantom units		—		—		0.1		0.1
Amortization of phantom units		—		—		1.8		1.8
Adjustment to ASC 480 redemption value		—		—		(5.5)		(5.5)
Balance at September 30, 2022	$	(9.9)	$	1.9	$	(457.4)	$	(465.4)

See accompanying notes to unaudited condensed consolidated financial statements.

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	Accumulated
	Other		Partners’ Capital (Deficit)
	Comprehensive		General		Limited
	Loss		Partner		Partners		Total
	(In millions)
Balance at December 31, 2021	$	(10.1)	$	3.8	$	(378.8)	$	(385.1)
Other comprehensive income		0.2		—		—		0.2
Net loss attributable to partners		—		(1.9)		(93.2)		(95.1)
Settlement of tax withholdings on equity-based incentive compensation		—		—		(4.1)		(4.1)
Settlement of phantom units		—		—		6.7		6.7
Modification of phantom units		—		—		13.5		13.5
Amortization of phantom units		—		—		4.0		4.0
Adjustment to ASC 480 redemption value		—		—		(5.5)		(5.5)
Balance at September 30, 2022	$	(9.9)	$	1.9	$	(457.4)	$	(465.4)

See accompanying notes to unaudited condensed consolidated financial statements.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS


	~~Nine~~Three Months Ended ~~September~~March 3031,
	~~2023~~2024		~~2022~~2023
	(In millions)
Operating activities			(As Restated)
Net income (loss)	$	94(41.76)	$	~~(96~~18.2)6
Non-cash RINs (gain) expense		(134.0)		151.3
Non-cash RINs gain		(64.6)		(32.1)
Unrealized (gain) loss on derivative instruments		~~(18~~17.8)5		47(41.50)
Other non-cash activities		~~147~~47.48		~~141~~66.53
Changes in assets and liabilities		(9653.71)		(9338.45)
Net cash provided by (used in) operating activities		(7.4)		150.7
Net cash used in operating activities		(94.0)		(26.7)
Investing activities
Additions to property, plant and equipment		(~~240~~20.30)		(~~376~~130.34)
Other investing activities		—		0.2
Net cash used in investing activities		(20.0)		(130.4)
Net cash used in investing activities		(240.3)		(376.1)
Financing activities
Proceeds from borrowings — revolving credit facility		~~1,585~~596.68		~~1,139~~559.0
Repayments of borrowings — revolving credit facility		(~~1,618~~423.57)		(~~1,052~~437.0)
Proceeds from borrowings — MRL revolving credit agreement		7932.0		—18.7
Repayments of borrowings — MRL revolving credit agreement		(7922.03)		—
Proceeds from borrowings — senior notes		~~325~~200.0		~~325.0~~—
Repayments of borrowings — senior notes		(~~121~~179.0)		~~(363.1)~~—
Proceeds from inventory financing		~~1,229~~280.37		~~1,598~~388.25
Payments on inventory financing		(~~1,235~~336.28)		(~~1,603~~404.61)
Proceeds from sale of redeemable noncontrolling interest in subsidiary		—		200.0
Proceeds from other financing obligations		—		20.8
Repayment of MRL credit facility		—		(347.3)
Payments on other financing obligations		(17.0)		(12.8)
Proceeds from other financing obligations		101.5		279.6
Net cash provided by financing activities		130.7		133.1
Payments on other financing obligations		(33.8)		(21.8)
Net increase (decrease) in cash, cash equivalents and restricted cash		16.7		(24.0)
Net cash provided by financing activities		232.9		154.0
Cash, cash equivalents and restricted cash at beginning of period		14.7		35.2
Net decrease in cash, cash equivalents and restricted cash		(14.8)		(71.4)
Cash, cash equivalents and restricted cash at end of period	$	31.4	$	11.2
Cash, cash equivalents and restricted cash at beginning of period		35.2		121.9
Cash and cash equivalents	$	23.9	$	11.2
Cash, cash equivalents and restricted cash at end of period	$	20.4	$	50.5
Restricted cash	$	7.5	$	—
Cash and cash equivalents	$	13.7	$	50.5
Restricted cash	$	6.7	$	—
Supplemental disclosure of non-cash investing activities
Non-cash property, plant and equipment additions	$	3125.72	$	~~121~~95.81

See accompanying notes to unaudited condensed consolidated financial statements.

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CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Description of the Business

Calumet Specialty Products Partners, L.P. (the “Company” or “Calumet”) is a publicly traded Delaware limited partnership. Its common units are listed on the Nasdaq Global Select Market under the ticker symbol “CLMT.” The general partner of the Company is Calumet GP, LLC, a Delaware limited liability company. As of ~~September~~March 3031, ~~2023~~2024, the Company had 7980,~~964~~223,~~002~~093 limited partner common units and 1,~~631~~637,~~918~~206 general partner equivalent units outstanding. The general partner owns 2% of the Company and all of the incentive distribution rights (as defined in the Company’s partnership agreement), while the remaining 98% is owned by limited partners. The general partner employs the Company’s employees and the Company reimburses the general partner for certain of its expenses.

The Company manufactures, formulates, and markets a diversified slate of specialty branded products and renewable fuels to customers in various consumer-facing and industrial markets. Calumet is headquartered in Indianapolis, Indiana and operates twelve facilities throughout North America.

The unaudited condensed consolidated financial statements of the Company as of ~~September~~March 3031, ~~2023~~2024 and for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023, included herein have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with generally accepted accounting principles (“GAAP”) in the U.S. have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the following disclosures are adequate to make the information presented not misleading. The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the unaudited condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. These unaudited condensed consolidated financial statements reflect all adjustments that, in the opinion of management, are necessary to present fairly the results of operations for the interim periods presented. All adjustments are of a normal nature, unless otherwise disclosed. The results of operations for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024 are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2023~~2024. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, ~~2022~~2023 (“~~2022~~2023 Annual Report”).

2. Summary of Significant Accounting Policies

Reclassifications

Certain amounts in the prior years’ unaudited condensed consolidated financial statements have been reclassified to conform to the current year presentation.

Cash, Cash Equivalents and Restricted Cash

Cash, cash equivalents and restricted cash include all highly liquid investments with a maturity of three months or less at the time of purchase.

Restricted cash represents cash that is legally restricted under the Montana Renewables, LLC (“MRL”) Term Loan Credit Agreement, and it is included in prepaid expenses and other current assets in the condensed consolidated balance sheets because it is only available to make principal and interest payments under the terms of the agreement.

Renewable Identification Numbers (“RINs”) Obligation

The Company’s RINs volume obligation (“RVO” or “RINs Obligation”) is an estimated provision if future purchase of RINs were to be required in order to satisfy the U.S. Environmental Protection Agency’s (“EPA”) requirement to blend

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renewable fuels into certain transportation fuel products pursuant to the Renewable Fuel Standard (“RFS”) of the Clean Air Act (“CAA”). The Company has historically not been obligated to make these purchases. A RIN is a 38-character number assigned to each physical gallon of renewable fuel produced in or imported into the United States. The EPA sets annual volume obligations for the percentage of renewable fuels that must be blended into transportation fuels consumed in the U.S. Compliance is demonstrated by tendering RINs to the EPA documenting that blending has been accomplished or by obtaining a Small Refinery Exemption as provided in the Clean Air Act. Prior to 2018, the Company historically received the Small Refinery Exemption after qualifying on the merits. The Company’s petitions for the Small Refinery Exemption for compliance years 2018-2022 ultimately were denied by the EPA. EPA’s denials of those petitions is subject to litigation, as described below. Future exemptions are the subject of future annual applications. The RIN obligation is a non-financial instrument representing a quantity that cannot be settled financially.

The Company accounts for its current period RVO by multiplying the quantity of RINs shortage (based on actual results) by the period end RINs spot price, which is recorded as a current liability in the condensed consolidated balance sheets. These liabilities are revalued at the end of each subsequent accounting period, which produce non-cash mark-to-market adjustments that are reflected in cost of sales in the unaudited condensed consolidated statements of operations (with the exception of RINs for compliance year 2019 related to the San Antonio refinery, which amount is reflected in other operating expense in the unaudited condensed consolidated statements of operations). RINs generated by blending may be sold or held to offset future RVO. Any gains or losses from RINs sales are recorded in cost of sales in the unaudited condensed consolidated statements of operations.

The RFS provision of the CAA allows small refineries to apply at any time for a Small Refinery Exemption (“SRE”) from the renewable blending requirements, and we have applied in respect of compliance years 2019, 2020, 2021, 2022 and 2023.

2018 RVO. In April 2022, EPA issued new decisions denying 36 petitions from small refineries seeking SREs for program year 2018 that had been remanded by the U.S. Court of Appeals for the D.C. Circuit to EPA. EPA had previously granted 31 of these 36 petitions in August 2019, including petitions from the Company. Concurrent with the April 2022 denial action, EPA provided an alternate compliance approach to allow these 31 small refineries to meet their 2018 compliance obligations without purchasing or redeeming additional RINs. In April 2022, the Company filed a petition for review of EPA’s denial of the 2018 SRE petition for the Shreveport refinery in the U.S. Court of Appeals for the Fifth Circuit. In June 2022, the Company filed a petition for review of EPA’s denial of the 2018 SRE petition for the Montana refinery in the U.S. Court of Appeals for the Ninth Circuit and filed a protective petition for review in the U.S. Court of Appeals for the D.C. Circuit challenging the EPA’s denials of both the Shreveport and Montana refineries’ petitions. Upon a motion made by EPA, the Ninth Circuit dismissed the Company’s appeal of the denial of the Montana refinery’s 2018 SRE petition for improper venue in favor of the D.C. Circuit appeal. EPA filed a similar motion to dismiss or transfer in the Fifth Circuit; however, the Fifth Circuit denied EPA’s motion and ordered the merits panel to consider both the merits of the appeal and the venue question raised by EPA. These 2018 RVO appeals were consolidated with the 2019-2020 RVO appeals described below.

2019-2020 RVO. In June 2022, EPA issued final decisions denying 69 pending petitions from small refineries seeking SREs for compliance years 2016 to 2021, including petitions submitted by the Company seeking exemptions for program years 2019 and 2020, based on an across-the-board determination that no small refinery suffers disproportionate economic hardship from the RFS program, a contention which was subsequently rejected by the Government Accountability Office. In September 2022, EPA finalized an alternative RIN retirement schedule for small refineries. The alternative RIN retirement schedule allows the use of RINs generated in post-2020 compliance years to meet the 2020 RFS obligations. The Company’s small refineries are eligible to use this alternative schedule. In August 2022, the Company filed a petition for review of EPA’s denial of the 2019 and 2020 SRE petitions for the Shreveport refinery in the U.S. Court of Appeals for the Fifth Circuit, and a petition for review of EPA’s denial of the 2019 and 2020 SRE petitions for the Montana refinery in the U.S. Court of Appeals for the Ninth Circuit. The Company again filed a protective petition for review in the U.S. Court of Appeals for the D.C. Circuit challenging both of the EPA’s denials. These appeals have been consolidated with the applicable program year 2018 appeals. Upon a motion made by EPA, the Ninth Circuit transferred the Company’s Montana appeal, which is now pending in the D.C. Circuit. The Fifth Circuit denied EPA’s request to dismiss or transfer the appeal, ruling that merits panel will also consider EPA’s argument that the Shreveport refinery appeals should be transferred to the D.C. Circuit. The Company filed motions in both appeals asking the circuit

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~~renewable~~courts ~~fuels into certain transportation fuel products pursuant~~ to stay the ~~Renewable~~Company’s ~~Fuel~~2019 ~~Standard~~and (“2020 RFS”) ofobligations while the ~~Clean~~merits ~~Air~~appeals ~~Act~~are ~~(“CAA”)~~pending. ~~The~~In ~~Company~~January 2023, ~~has~~the ~~historically~~Fifth ~~not~~Circuit ~~been~~granted ~~obligated~~the toCompany’s ~~make~~motion ~~these~~for ~~purchases.~~stay Arelating ~~RIN~~to isthe aShreveport ~~38-character~~refinery, ~~number~~and ~~assigned~~in toMarch 2023, ~~each~~the ~~physical~~D.C. ~~gallon~~Circuit ofgranted ~~renewable~~the ~~fuel~~Company’s ~~produced~~motion infor orstay ~~imported~~relating ~~into~~to the ~~United~~Montana ~~States~~refinery. The ~~EPA~~stays ~~sets~~granted ~~annual~~by ~~volume~~each ~~obligations~~of ~~for~~ the ~~percentage~~ ofrespective ~~renewable~~circuits ~~fuels~~hold that ~~must~~the beCompany ~~blended~~is ~~into~~likely ~~transportation~~to ~~fuels~~be ~~consumed~~successful inon the ~~U.S.~~merits ~~Compliance~~of isits ~~demonstrated~~appeals. byIn ~~tendering~~November ~~RINs~~2023, to the ~~EPA~~Fifth ~~documenting~~Circuit ~~that~~issued ~~blending~~its ~~has~~decision ~~been~~and ~~accomplished~~found orthat byvenue ~~obtaining~~for athe ~~Small~~appeal ~~Refinery~~is ~~Exemption~~proper ~~as provided~~ in the ~~Clean~~Fifth ~~Air~~Circuit ~~Act.~~and ~~The~~that ~~Company~~EPA’s ~~has~~denial ~~historically~~of ~~received~~ the ~~Small~~Shreveport ~~Refinery~~refinery’s ~~Exemption~~petitions ~~after~~for ~~qualifying~~program onyears ~~the~~2018-2020 ~~merits~~was improper. ~~Future~~The ~~exemptions~~Fifth ~~are~~Circuit vacated the ~~subject~~EPA’s denials of ~~future~~those ~~annual~~petitions ~~applications. The RIN obligation is a quantity,~~ and ~~cannot~~remanded bethe ~~settled~~petitions ~~financially~~to EPA.

~~The~~2021-2022 ~~Company~~RVO. ~~accounts~~In October 2022, Calumet applied for ~~its~~SREs ~~current~~for ~~period~~2021 ~~RVO~~and by2022 ~~multiplying~~compliance years. In April 2023, the ~~quantity~~Company offiled ~~RINs~~for ~~shortage~~injunctive ~~(based~~relief onin ~~actual~~both ~~results)~~the byDistrict Court of Montana and the ~~period~~Western ~~end~~District ~~RINs~~Court ~~spot~~of ~~price,~~Louisiana ~~which~~to isforce ~~recorded~~EPA asto ~~both~~make a ~~current~~decision on the Montana and ~~long-term~~Shreveport ~~liability~~refineries’ injoint ~~the~~2021 ~~condensed~~and ~~consolidated~~2022 ~~balance~~SRE ~~sheets~~applications. ~~These~~In ~~liabilities~~July ~~are~~2023, ~~revalued~~EPA atissued ~~the~~final ~~end~~decisions ofdenying ~~each~~26 ~~subsequent~~pending ~~accounting~~petitions ~~period,~~from ~~which~~small ~~produce~~refineries ~~non-cash~~seeking ~~mark-to-market~~SREs ~~adjustments~~for ~~that~~compliance ~~are~~years ~~reflected~~2016 into ~~cost~~2023, ofincluding ~~sales~~petitions insubmitted by the ~~unaudited~~Company ~~condensed~~seeking ~~consolidated~~exemptions ~~statements~~for ofprogram ~~operations~~years ~~(with~~2021 and 2022, based on the ~~exception~~same ofapproach ~~RINs~~and ~~for~~analysis ~~compliance year~~described ~~2019~~in ~~related~~the toJune 2022 denials. EPA’s denial decision renders the ~~San~~district ~~Antonio~~court ~~refinery~~actions moot, ~~which~~and ~~amount~~the isCompany ~~reflected~~voluntarily indismissed ~~other~~those ~~operating~~actions. ~~expense~~The inCompany then filed appeals of the ~~unaudited~~denials ~~condensed~~with ~~consolidated~~the ~~statements~~Fifth ofCircuit ~~operations)~~and D.C. ~~RINs~~Circuit. ~~generated~~In bySeptember ~~blending~~2023, ~~may~~the beFifth ~~sold~~Circuit orgranted ~~held~~the Company’s motion for stay relating to ~~offset~~the ~~future~~Shreveport ~~RVO.~~refinery ~~Any~~for ~~gains~~its orappeal ~~losses~~of ~~from~~the ~~RINs~~denial ~~sales~~for ~~are~~program ~~recorded~~years in2021 ~~cost~~and of2022, ~~sales~~and in October 2023, the ~~unaudited~~D.C. ~~condensed~~Circuit ~~consolidated~~granted ~~statements~~the ofCompany’s ~~operations.~~motion ~~The~~for ~~liabilities~~stay ~~associated~~relating ~~with~~to the Montana refinery’s appeal of the denial for program years 2021 and 2022. The Company’s ~~RVO~~appeals ~~are~~of ~~considered~~the ~~recurring~~denial ~~fair~~of ~~value~~the ~~measurement~~Shreveport and Great Falls refinery petitions for program years 2021 and 2022 remain pending in the Fifth Circuit and D.C. Circuit, respectively.

In September 2022, EPA finalized, and in July 2023, EPA amended, an alternative RIN retirement schedule for small refineries as set forth below:

Compliance Year		RINs Retirement Due Date
2019		Calumet carried forward its 2019 RVO into the 2020 compliance year as provided under the RFS. Calumet’s 2019 RVO is now due with the 2020 RVO.
2020		Under the Alt RIN Retirement schedule, five installments of 20% are due: February 1, 2023May 1, 2023August 1, 2023November 1, 2023February 1, 2024However, the Fifth Circuit has granted the Shreveport refinery’s motion to stay enforcement while the appeal is pending. A similar motion regarding the Montana refinery was granted by the D.C. Circuit.
2021		March 31, 2023
2022		December 1, 2023

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2018 RVO. In April 2022, EPA issued new decisions denying 36 petitions from small refineries seeking SREs for program year 2018 that had been remanded by the U.S. Court of Appeals for the D.C. Circuit to EPA. EPA had previously granted 31 of these 36 petitions in August 2019, including petitions from the Company. Concurrent with the April 2022 denial action, EPA provided an alternate compliance approach to allow these 31 small refineries to meet their 2018 compliance obligations without purchasing or redeeming additional RINs. In April 2022, the Company filed a petition for review of EPA’s denial of the 2018 SRE petition for the Shreveport refinery in the U.S. Court of Appeals for the Fifth Circuit. In June 2022, the Company filed a petition for review of EPA’s denial of the 2018 SRE petition for the Montana refinery in the U.S. Court of Appeals for the Ninth Circuit and filed a protective petition for review in the U.S. Court of Appeals for the D.C. Circuit challenging the EPA’s denials of both the Shreveport and Montana refineries’ petitions. Upon a motion made by EPA, the Ninth Circuit dismissed the Company’s appeal of the denial of the Montana refinery’s 2018 SRE petition for improper venue in favor of the D.C. Circuit appeal. EPA filed a similar motion to dismiss or transfer in the Fifth Circuit; however, the Fifth Circuit denied EPA’s motion and ordered the merits panel to consider both the merits of the appeal and the venue question raised by EPA. These 2018 RVO appeals have been consolidated with the 2019-2020 RVO appeals described below.

2019-2020 RVO. In June 2022, EPA issued final decisions denying 69 pending petitions from small refineries seeking SREs for compliance years 2016 to 2021, including petitions submitted by the Company seeking exemptions for program years 2019 and 2020, based on an across-the-board determination that no small refinery suffers disproportionate economic hardship from the RFS program, a contention which was subsequently rejected by the Government Accountability Office. In September 2022, EPA finalized an alternative RIN retirement schedule for small refineries as set forth above. The alternative RIN retirement schedule allows the use of RINs generated in post-2020 compliance years to meet the 2020 RFS obligations. The Company’s small refineries are eligible to use this alternative schedule. In August 2022, the Company filed a petition for review of EPA’s denial of the 2019 and 2020 SRE petitions for the Shreveport refinery in the U.S. Court of Appeals for the Fifth Circuit, and a petition for review of EPA’s denial of the 2019 and 2020 SRE petitions for the Montana refinery in the U.S. Court of Appeals for the Ninth Circuit. The Company again filed a protective petition for review in the U.S. Court of Appeals for the D.C. Circuit challenging both of the EPA’s denials. These appeals have been consolidated with the applicable program year 2018 appeals. Upon a motion made by EPA, the Ninth Circuit transferred the Company’s Montana appeal, which is now pending in the D.C. Circuit. The Fifth Circuit denied EPA’s request to dismiss or transfer the appeal, ruling that merits panel will also consider EPA’s argument that the Shreveport refinery appeals should be transferred to the D.C. Circuit. The Company filed motions in both appeals asking the circuit courts to stay the Company’s 2019 and 2020 RFS obligations while the merits appeals are pending. In January 2023, the Fifth Circuit granted the Company’s motion for stay relating to the Shreveport refinery, and in March 2023, the D.C. Circuit granted the Company’s motion for stay relating to the Montana refinery. The stays granted by each of the respective circuits hold that the Company is likely to be successful on the merits of its appeals.

2021-2022 RVO. In October 2022, Calumet applied for SREs for 2021 and 2022 compliance years. In April 2023, the Company filed for injunctive relief in both the District Court of Montana and the Western District Court of Louisiana to force EPA to make a decision on the Montana and Shreveport refineries’ joint 2021 and 2022 SRE applications. In July 2023, EPA issued final decisions denying 26 pending petitions from small refineries seeking SREs for compliance years 2016 to 2023, including petitions submitted by the Company seeking exemptions for program years 2021 and 2022, based on the same approach and analysis described in the June 2022 denials. An effect of the denials is to make the district court actions moot, and the Company voluntarily dismissed those actions. The Company filed appeals of the denials with the Fifth Circuit and D.C. Circuit. In September 2023, the Fifth Circuit granted the Company’s motion for stay relating to the Shreveport refinery for its appeal of the denial for program years 2021 and 2022, and in October 2023, the D.C. Circuit granted the Company’s motion for stay relating to the Montana refinery’s appeal of the denial for program years 2021 and 2022.

Expenses related to RFS compliance have the potential to remain a significant expense for the Specialty Products and Solutions and Montana/Renewables segments. If legal or regulatory changes occur that have the effect of increasing the RINs Obligation, increasing the market price of RINs, or eliminating or narrowing the availability of SREs, the Company could be required to purchase additional RINs in the open market, which may materially increase the costs related to RFS compliance and could have a material adverse effect on the results of operations and liquidity.

12As of March 31, 2024 and December 31, 2023, the Company had a RINs Obligation recorded on the condensed consolidated balance sheets of $212.7 million and $277.3 million, respectively.

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As of September 30, 2023 and December 31, 2022, the Company had a RINs Obligation recorded on the condensed consolidated balance sheets of $342.8 million and $476.8 million, respectively.

3. Revenue Recognition

The following is a description of principal activities from which the Company generates revenue. Revenues are recognized when control of the promised goods are transferred to the customer, in an amount that reflects the consideration to which the Company expects to be entitled in exchange for those goods. To determine revenue recognition for arrangements that an entity determines are within the scope of ASC 606, the Company performs the following five steps: (i) identify the contract(s) with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when (or as) the entity satisfies a performance obligation. At contract inception, once the contract is determined to be within the scope of ASC 606, the Company assesses the goods promised within each contract and determines the performance obligations and assesses whether each promised good is distinct. The Company then recognizes as revenue the amount of the transaction price that is allocated to the respective performance obligation when (or as) the performance obligation is satisfied.

Products

The Company manufactures, formulates, and markets a diversified slate of specialty branded products to customers in various consumer-facing and industrial markets. In addition, the Company produces fuel and fuel related products, including gasoline, diesel, jet fuel, asphalt, and other fuels products. At our Montana Renewables facility, we process a variety of geographically advantaged renewable feedstocks into renewable fuels, including: renewable diesel, sustainable aviation fuel (“SAF”), 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. The Company also blends, packages and markets high-performance branded specialty products through its Royal Purple, Bel-Ray, and TruFuel brands.

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The Company considers customer purchase orders, which in some cases are governed by master sales agreements, to be the contracts with a customer. For each contract, the Company considers the promise to transfer products, each of which are distinct, to be the identified performance obligations. In determining the transaction price, the Company evaluates whether the price is subject to variable consideration such as product returns, rebates or other discounts to determine the net consideration to which the Company expects to be entitled. The Company transfers control and recognizes revenue upon shipment to the customer or, in certain cases, upon receipt by the customer in accordance with contractual terms.

Revenue is recognized when obligations under the terms of a contract with a customer are satisfied and control of the promised goods are transferred to the customer. The contract with the customer states the final terms of the sale, including the description, quantity and price of each product or service purchased. For fuel products, payment is typically due in full between 2 to 30 days of delivery or the start of the contract term, such that payment is typically collected 2 to 30 days subsequent to the satisfaction of performance obligations. For renewable fuel products, payment is typically due in full between 7 to 14 days of delivery or the start of the contract term, such that payment is typically collected 7 to 14 days subsequent to the satisfaction of performance obligations. For specialty products, payment is typically due in full between 30 to 90 days of delivery or the start of the contract term, such that payment is typically collected 30 to 90 days subsequent to the satisfaction of performance obligations. In the normal course of business, the Company does not accept product returns unless the item is defective as manufactured. The expected costs associated with a product assurance warranty continue to be recognized as expense when products are sold. The Company does not offer promised services that could be considered warranties that are sold separately or provide a service in addition to assurance that the related product complies with agreed upon specifications. The Company establishes provisions based on the methods described in ASC 606 for estimated returns as variable consideration when determining the transaction price.

Excise and Sales Taxes

The Company assesses, collects and remits excise taxes associated with the sale of certain of its fuel products. Furthermore, the Company collects and remits sales taxes associated with certain sales of its products to non-exempt customers. The Company excludes excise taxes and sales taxes that are collected from customers from the transaction price in its contracts with customers. Accordingly, revenue from contracts with customers is net of sales-based taxes that are collected from customers and remitted to taxing authorities.

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customers. The Company excludes excise taxes and sales taxes that are collected from customers from the transaction price in its contracts with customers. Accordingly, revenue from contracts with customers is net of sales-based taxes that are collected from customers and remitted to taxing authorities.

Shipping and Handling Costs

Shipping and handling costs are deemed to be fulfillment activities rather than a separate distinct performance obligation.

Cost of Obtaining Contracts

The Company may incur incremental costs to obtain a sales contract, which under ASC 606 should be capitalized and amortized over the life of the contract. The Company has elected to apply the practical expedient in ASC 340-40-50-5 allowing the Company to expense these costs since the contracts are short-term in nature with a contract term of one year or less.

Contract Balances

Under product sales contracts, the Company invoices customers for performance obligations that have been satisfied, at which point payment is unconditional. Accordingly, a product sales contract does not give rise to contract assets or liabilities under ASC 606. The Company’s receivables, net of allowance for expected credit losses from contracts with customers as of ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023 were $~~285~~289.04 million and $~~245~~252.74 million, respectively.

Transaction Price Allocated to Remaining Performance Obligations

The Company’s product sales are short-term in nature with a contract term of one year or less. The Company has utilized the practical expedient in ASC 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. Additionally, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

~~4. Inventories~~12

The cost of inventory is recorded using the last-in, first-out (“LIFO”) method. An actual valuation of inventory under the LIFO method can be made only at the end of each year based on the inventory levels and costs at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and costs and are subject to the final year-end LIFO inventory valuation. In certain circumstances, the Company may decide not to replenish inventory for certain products or product lines during an interim period, in which case, the Company may record interim LIFO adjustments during that period. During the three and nine months ended September 30, 2023, the Company recorded increases (exclusive of lower of cost or market (“LCM”) adjustments) in cost of sales in the unaudited condensed consolidated statements of operations of $7.5 million due to the permanent liquidation of inventory layers. During the three and nine months ended September 30, 2022, the Company recorded decreases (exclusive of LCM adjustments) in cost of sales in the unaudited condensed consolidated statements of operations of $4.7 million due to the permanent liquidation of inventory layers.

Costs include crude oil and other feedstocks, labor, processing costs and refining overhead costs. Inventories are valued at the LCM value. The replacement cost of these inventories, based on current market values, would have been $104.3 million and $99.9 million higher than the carrying value of inventory as of September 30, 2023 and December 31, 2022, respectively.

On March 31, 2017, June 19, 2017, and November 2, 2022, the Company sold inventory comprised of crude oil, refined products and renewable feedstocks to Macquarie Energy North America Trading Inc. (“Macquarie”) under Supply

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~~and~~expected ~~Offtake~~duration ~~Agreements~~of asone year ~~described~~or ~~in Note 7 -~~less. ~~“Inventory~~Additionally, ~~Financing~~each ~~Agreements”~~unit ~~related~~of toproduct ~~the~~generally ~~Great~~represents ~~Falls~~a separate performance obligation; therefore, ~~Shreveport~~future volumes are wholly unsatisfied and ~~Montana~~disclosure ~~Renewables~~of ~~facilities,~~the ~~respectively~~transaction price allocated to remaining performance obligations is not required.

4. Inventories

The cost of inventory is recorded using the last-in, first-out (“LIFO”) method. An actual valuation of inventory under the LIFO method can be made only at the end of each year based on the inventory levels and costs at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and costs and are subject to the final year-end LIFO inventory valuation. In certain circumstances, the Company may decide not to replenish inventory for certain products or product lines during an interim period, in which case, the Company may record interim LIFO adjustments during that period. During the three months ended March 31, 2024 and 2023, the Company recorded no activity (exclusive of lower of cost or market (“LCM”) adjustments) in cost of sales in the unaudited condensed consolidated statements of operations due to the permanent liquidation of inventory layers.

Costs include crude oil and other feedstocks, labor, processing costs and refining overhead costs. Inventories are valued at the LCM value. The replacement cost of these inventories, based on current market values, would have been $75.5 million and $67.8 million higher than the carrying value of inventory as of March 31, 2024 and December 31, 2023, respectively.

For the three months ended March 31, 2024 and 2023, the Company sold inventory comprised of crude oil, refined products and renewable feedstocks under Supply and Offtake Agreements as described in Note 7 — “Inventory Financing Agreements” related to the Great Falls, Shreveport and Montana Renewables facilities.

Inventories consist of the following (in millions):


	~~September~~March 3031, ~~2023~~2024						December 31, ~~2022~~2023
			Supply and						Supply and
	Titled		Offtake				Titled		Offtake
	Inventory		Agreements (1)		Total		Inventory		Agreements (1)		Total
Raw materials	$	7156.08	$	3851.14	$	~~109~~108.12	$	9961.6	$	2227.56	$	~~122~~89.12
Work in process		6264.43		5131.52		~~113~~95.95		6272.53		9536.7		~~158~~109.20
Finished goods		~~137~~153.39		8745.45		~~224~~199.74		~~137~~162.31		8079.41		~~217~~241.72
	$	~~270~~275.70	$	~~177~~128.01	$	~~447~~403.71	$	~~299~~296.40	$	~~198~~143.64	$	~~498~~439.04

(1) Amounts represent LIFO value and do not necessarily represent the value at which the inventory was sold. Please read Note 7 -— “Inventory Financing Agreements” for further information.

In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. During the three months ended ~~September~~March 3031, ~~2023~~2024 and 2022, the Company recorded a decrease in cost of sales in the unaudited condensed consolidated statements of operations of $12.0 million and an increase in cost of sales of $4.2 million, respectively. During the nine months ended September 30, 2023 ~~and 2022~~, the Company recorded an increase in cost of sales in the unaudited condensed consolidated statements of operations of $1.9.0 million and ~~a decrease in cost of sales of~~ $319.07 million, respectively.

5. Leases

The Company has various operating and finance leases primarily for the use of land, storage tanks, railcars, equipment, precious metals and office facilities that have remaining lease terms of greater than one year to 16 years, some of which include options to extend the lease for up to 3231 years, and some of which include options to terminate the lease within one year.

~~Supplemental balance sheet information related to the Company’s leases for the periods presented were as follows (in millions):~~13


		September 30,		December 31,
Assets:	Classification:	2023		2022
Operating lease assets	Other noncurrent assets, net	$	75.9	$	107.5
Finance lease assets	Property, plant and equipment, net (1)		2.4		2.8
Total leased assets		$	78.3	$	110.3
Liabilities:
Current
Operating	Other current liabilities	$	34.9	$	70.7
Finance	Current portion of long-term debt		1.0		0.9
Non-current
Operating	Other long-term liabilities		41.3		37.1
Finance	Long-term debt, less current portion		2.0		2.5
Total lease liabilities		$	79.2	$	111.2

(1) Finance lease assets are recorded net of accumulated amortization of $4.7 million and $4.1 million as of September 30, 2023 and December 31, 2022, respectively.

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Supplemental balance sheet information related to the Company’s leases for the periods presented were as follows (in millions):


		March 31,		December 31,
Assets:	Classification:	2024		2023
Operating lease assets	Other noncurrent assets, net ⁽¹⁾	$	100.4	$	114.4
Finance lease assets	Property, plant and equipment, net ⁽²⁾		2.3		2.4
Total leased assets		$	102.7	$	116.8
Liabilities:
Current
Operating	Other current liabilities	$	63.2	$	75.6
Finance	Current portion of long-term debt		1.0		1.1
Non-current
Operating	Other long-term liabilities		37.5		39.0
Finance	Long-term debt, less current portion		1.7		1.9
Total lease liabilities		$	103.4	$	117.6

(1)	During the three months ended March 31, 2024, the Company had additions to its operating lease right of use assets and operating lease liabilities of approximately $5.0 million.

(2)	Finance lease assets are recorded net of accumulated amortization of $5.1 million and $5.0 million as of March 31, 2024 and December 31, 2023, respectively.

Lease expense for lease payments is recognized on a straight-line basis over the lease term. The components of lease expense related to the Company’s leases for the periods presented were as follows (in millions).

Three Months Ended ~~September~~March 3031,

~~Nine Months Ended September 30,~~

Lease Costs:

Classification:

~~2023~~2024

~~2022~~2023

~~2023~~

~~2022~~

Fixed operating lease cost

Cost of Sales; SG&A Expenses

20.19

1819.70

~~55.7~~

~~56.2~~

Short-term operating lease cost (1)

Cost of Sales; SG&A Expenses

2.43

2.2

~~7.2~~

~~6.0~~

Variable operating lease cost (2)

Cost of Sales; SG&A Expenses

0.57

72.57

~~3.3~~

~~13.5~~

Finance lease cost:

Amortization of finance lease assets

Cost of Sales

0.1

0.2

~~0.6~~

Interest on lease liabilities

Interest expense

0.1

~~0.2~~

~~1.3~~

Total lease cost

2324.21

2824.72

~~67.0~~

~~77.6~~

(1)	The Company’s leases with an initial term of 12 months or less are not recorded on the condensed consolidated balance sheets.

(2)	The Company’s railcar leases typically include a mileage limit the railcar can travel over the life of the lease. For any mileage incurred over this limit, the Company is obligated to pay an agreed upon dollar value for each mile that is traveled over the limit.

As of September 30, 2023, the Company had estimated minimum commitments for the payment of rentals under leases which, at inception, had a noncancellable term of more than one year, as follows (in millions):14


	Operating		Finance
Maturity of Lease Liabilities	Leases (1)		Leases (2)		Total
2023	$	20.4	$	0.3	$	20.7
2024		24.0		1.2		25.2
2025		18.0		0.8		18.8
2026		9.0		0.7		9.7
2027		6.3		0.2		6.5
Thereafter		8.6		0.1		8.7
Total	$	86.3	$	3.3	$	89.6
Less: Interest		10.1		0.3		10.4
Present value of lease liabilities	$	76.2	$	3.0	$	79.2
Less obligations due within one year		34.9		1.0		35.9
Long-term lease obligation	$	41.3	$	2.0	$	43.3

(1) As of September 30, 2023, the Company’s operating lease payments included no material options to extend lease terms that are reasonably certain of being exercised. The Company has no legally binding minimum lease payments for leases signed but not yet commenced as of September 30, 2023.

(2) As of September 30, 2023, the Company’s finance lease payments included no material options to extend lease terms that are reasonably certain of being exercised. The Company has no legally binding minimum lease payments for leases that have been signed but not yet commenced as of September 30, 2023.

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As of March 31, 2024, the Company had estimated minimum commitments for the payment of rentals under leases which, at inception, had a noncancellable term of more than one year, as follows (in millions):


	Operating		Finance
Maturity of Lease Liabilities	Leases ⁽¹⁾		Leases ⁽²⁾		Total
2024	$	62.4	$	0.9	$	63.3
2025		20.5		0.9		21.4
2026		11.4		0.8		12.2
2027		7.5		0.3		7.8
2028		4.7		0.1		4.8
Thereafter		4.8		—		4.8
Total	$	111.3	$	3.0	$	114.3
Less: Interest		10.6		0.3		10.9
Present value of lease liabilities	$	100.7	$	2.7	$	103.4
Less obligations due within one year		63.2		1.0		64.2
Long-term lease obligation	$	37.5	$	1.7	$	39.2

(1)	As of March 31, 2024, the Company’s operating lease payments included no material options to extend lease terms that are reasonably certain of being exercised. The Company has no legally binding minimum lease payments for leases signed but not yet commenced as of March 31, 2024.

(2)	As of March 31, 2024, the Company’s finance lease payments included no material options to extend lease terms that are reasonably certain of being exercised. The Company has no legally binding minimum lease payments for leases that have been signed but not yet commenced as of March 31, 2024.

Weighted-Average Lease Term and Discount Rate

The weighted-average remaining lease term and weighted-average discount rate for the Company’s operating and finance leases were as follows:


	~~September~~March 3031,		December 31,
Lease Term and Discount Rate:	~~2023~~2024		~~2022~~2023
Weighted-average remaining lease term (years):
Operating leases	32.36		2.76
Finance leases	3.30		3.91
Weighted-average discount rate:
Operating leases	78.6	%	68.96	%
Finance leases	7.35	%	7.13	%

6. Commitments and Contingencies

From time to time, the Company is a party to certain claims and litigation incidental to its business, including claims made by various taxation and regulatory authorities, such as the Internal Revenue Service, 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 the Company’s business. In addition, the Company has property, business interruption, general liability and various other insurance policies that may result in certain losses or expenditures being reimbursed to the Company.

Environmental

The Company conducts specialty refining, blending and terminal operations and such activities 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 obligations that are applicable to the Company’s operations, such as requiring the acquisition of permits to conduct regulated activities, restricting the manner in which the Company may release materials into the environment, requiring remedial activities or capital expenditures to mitigate pollution from former or current operations, requiring the application of specific health and safety criteria addressing worker protection and imposing substantial liabilities for pollution resulting from its operations. 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 delays in the permitting, development or expansion of projects and the issuance of injunctive relief limiting or prohibiting Company activities. Moreover, certain of these laws impose joint and several, strict liability for costs required to remediate and restore sites where petroleum hydrocarbons, wastes or other materials have been released or disposed. In addition, new laws and regulations, new interpretations of existing laws and regulations, increased governmental enforcement or other developments, some of which legal requirements are discussed below, could significantly increase the Company’s operational or compliance expenditures.

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in which the Company may release materials into the environment, requiring remedial activities or capital expenditures to mitigate pollution from former or current operations, requiring the application of specific health and safety criteria addressing worker protection and imposing substantial liabilities for pollution resulting from its operations. 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 delays in the permitting, development or expansion of projects and the issuance of injunctive relief limiting or prohibiting Company activities. Moreover, certain of these laws impose joint and several, strict liability for costs required to remediate and restore sites where petroleum hydrocarbons, wastes or other materials have been released or disposed. In addition, new laws and regulations, new interpretations of existing laws and regulations, increased governmental enforcement or other developments, some of which legal requirements are discussed below, could significantly increase the Company’s operational or compliance expenditures.

Remediation of subsurface contamination is in process at certain of the Company’s refinery sites and is being overseen by the appropriate state agencies. Based on current investigative and remedial activities, the Company believes that the soil and groundwater contamination at these refineries can be controlled or remediated without having a material adverse effect on the Company’s financial condition. However, such costs are often unpredictable and, therefore, there can be no assurance that the future costs will not become material.

Occupational Health and Safety

The Company is 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 the federal Comprehensive Environmental Response, Compensation and Liability Act, as amended, and similar state statutes require the Company to maintain information about hazardous materials used or produced in the Company’s operations and provide this information to employees, contractors, state and local government authorities and customers. The Company maintains safety and training programs as part of its ongoing efforts to promote compliance with applicable laws and regulations. The Company conducts periodic audits of process safety management systems at each of its locations subject to this standard. The Company’s compliance with applicable health and safety laws and regulations has required, and continues to require, substantial expenditures. Changes in occupational safety and health laws and regulations or a finding of non-compliance with current laws and regulations could result in additional capital expenditures or operating expenses, as well as civil penalties and, in the event of a serious injury or fatality, criminal charges.

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hazardous materials used or produced in the Company’s operations and provide this information to employees, contractors, state and local government authorities and customers. The Company maintains safety and training programs as part of its ongoing efforts to promote compliance with applicable laws and regulations. The Company conducts periodic audits of process safety management systems at each of its locations subject to this standard. The Company’s compliance with applicable health and safety laws and regulations has required, and continues to require, substantial expenditures. Changes in occupational safety and health laws and regulations or a finding of non-compliance with current laws and regulations could result in additional capital expenditures or operating expenses, as well as civil penalties and, in the event of a serious injury or fatality, criminal charges.

Other Matters, Claims and Legal Proceedings

The Company is subject to matters, claims and litigation incidental to its business. The Company has recorded accruals with respect to certain of its matters, claims and litigation where appropriate, that are reflected in the unaudited condensed consolidated financial statements but are not individually considered material. For other matters, claims and litigation, the Company has not recorded accruals because it has not yet determined that a loss is probable or because the amount of loss cannot be reasonably estimated. While the ultimate outcome of matters, claims and litigation currently pending cannot be determined, the Company currently does not expect these outcomes, individually or in the aggregate (including matters for which the Company has recorded accruals), to have a material adverse effect on its financial position, results of operations or cash flows. The outcome of any matter, claim or litigation is inherently uncertain, however, and if decided adversely to the Company, or if the Company determines that settlement of particular litigation is appropriate, the Company may be subject to liability that could have a material adverse effect on its financial position, results of operations or cash flows.

Standby Letters of Credit

The Company has agreements with various financial institutions for standby letters of credit, which have been issued primarily to vendors. As of ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023, the Company had outstanding standby letters of credit of $1843.76 million and $3529.89 million, respectively, under its senior secured revolving credit facility (the “revolving credit facility”). Please read Note 8 - “Long-Term Debt” for additional information regarding the Company’s revolving credit facility. At September 30, 2023 and December 31, 2022, the maximum amount of letters of credit the Company could issue under its revolving credit facility was subject to borrowing base limitations, with a maximum letter of credit sublimit equal to $255.0 million, which may be increased with the consent of the Agent (as defined in the Credit Agreement) to 90% of revolver commitments then in effect ($500.0 million at September 30, 2023 and December 31, 2022).

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credit facility. At March 31, 2024 and December 31, 2023, the maximum amount of letters of credit the Company could issue under its revolving credit facility was subject to borrowing base limitations, with a maximum letter of credit sublimit equal to $255.0 million, which may be increased with the consent of the Agent (as defined in the Credit Agreement) to 90% of revolver commitments then in effect ($500.0 million at March 31, 2024 and December 31, 2023).

Throughput Contract

Prior to 2020, the Company entered into a long-term agreement to transport crude oil at a minimum of 5,000 bpd through a pipeline, which commenced service in the second quarter of 2020. The agreement also contains a capital recovery charge that increases 2% per annum. This agreement is for seven years.

As of March 31, 2024, the estimated minimum unconditional purchase commitments, including the capital recovery charge, under the agreement were as follows (in millions):


Year	Commitment
2024	$	3.0
2025		4.0
2026		4.0
2027		2.4
Thereafter		—
Total ⁽¹⁾	$	13.4

~~Table~~(1) As of ~~Contents~~March 31, 2024, the estimated minimum payments for the unconditional purchase commitments have been accrued and are included in other current liabilities and other long-term liabilities in the condensed consolidated balance sheets. This liability was accrued due to the fact that the contract was entered into to supply crude to a divested facility.

As of September 30, 2023, the estimated minimum unconditional purchase commitments, including the capital recovery charge, under the agreement were as follows (in millions):


Year	Commitment
2023	$	0.9
2024		4.0
2025		4.0
2026		4.0
2027		2.4
Thereafter		—
Total (1)	$	15.3

(1) As of September 30, 2023, the estimated minimum payments for the unconditional purchase commitments have been accrued and are included in other current liabilities and other long-term liabilities in the condensed consolidated balance sheets. This liability was accrued due to the fact that the contract was entered into to supply crude to a divested facility.

7. Inventory Financing Agreements

~~The~~On ~~Company~~January is17, ~~party~~2024 to(the ~~several~~“Effective ~~agreements~~Date”), ~~with~~the ~~Macquarie~~Company toand ~~support~~J. ~~the~~Aron ~~operations~~entered ofinto ~~the~~a ~~Great~~Monetization ~~Falls~~Master ~~specialty~~Agreement ~~asphalt~~(the ~~facility~~“Master Agreement”), a related Financing Agreement (the ~~Shreveport~~“Financing ~~facility~~Agreement”) and ~~the~~Supply ~~Montana~~and ~~Renewables~~Offtake ~~facility~~Agreement (astogether ~~amended~~with the Master Agreement and the Financing Agreement, the “Shreveport Supply and Offtake ~~Agreements~~Agreement”). OnPursuant ~~March 20~~to the Shreveport Supply and Offtake Agreement, ~~2023~~J. Aron agreed to, ~~Macquarie~~among ~~provided~~other ~~notice~~things, ofpurchase ~~Macquarie’s~~from ~~election~~the ofCompany, ~~its~~or ~~right~~extend to ~~terminate~~ the ~~Great~~Company, ~~Falls~~financial ~~specialty~~accommodations ~~asphalt~~secured ~~facility~~by crude oil and finished products located at the Company’s Shreveport facility ~~agreements,~~on inthe ~~each~~Effective ~~case~~Date ~~effective~~and ~~December 31~~from time to time, ~~2023.~~up ~~The~~to ~~Montana~~maximum ~~Renewables~~volumes ~~agreement~~specified ~~was~~for ~~amended~~crude onoil ~~September~~and 26categories of finished products, ~~2023~~subject to ~~change~~the Company’s repurchase obligations with respect thereto. The Shreveport Supply and Offtake Agreement replaced the ~~expiration~~Company’s ~~date~~previous toinventory ~~October 3~~financing agreement with Macquarie, ~~2023~~which terminated on January 17, 2024.

~~The~~In ~~Supply~~March ~~and~~2017, ~~Offtake Agreements allow~~ the Company toentered ~~purchase~~into ~~crude~~an ~~oil,~~agreement ~~refined~~with ~~products~~Macquarie ~~and~~to ~~renewable~~support ~~feedstocks~~the ~~from~~operations ~~Macquarie~~of orthe ~~one~~Great ofFalls ~~its~~refinery ~~affiliates.~~(as ~~Per~~amended, the “Great Falls Supply and Offtake ~~Agreements,~~Agreement”). ~~Macquarie~~The ~~will~~Great ~~provide~~Falls upSupply ~~to 30,000~~and ~~barrels~~Offtake ~~per~~Agreement ~~day~~terminated ofon ~~crude~~December ~~oil to the Great Falls specialty asphalt facility~~13, ~~60,000~~2023. ~~barrels~~The ~~per~~inventories ~~day~~that ofwere ~~crude~~previously ~~oil~~associated towith the ~~Shreveport~~Great ~~facility,~~Falls Supply and ~~15,000~~Offtake ~~barrels~~Agreement ~~per~~were ~~day~~added ofback ~~renewable feedstocks~~ to ~~the~~our ~~Montana~~revolving ~~Renewables~~credit facility borrowing base.

~~While~~On ~~title~~October 3, 2023, MRL and Wells Fargo Commodities, LLC (“Wells Fargo”) entered into (a) an ISDA 2002 Master Agreement (the “Master Agreement”), (ii) a Schedule to ~~certain~~the ~~inventories~~ISDA ~~will~~2002 ~~reside~~Master Agreement (the “Schedule”), (iii) a Credit Support Annex to the ISDA 2002 Master Agreement (the “Credit Support Annex”), and (iv) a Renewable Fuel and Feedstock Repurchase Master Confirmation (together with ~~Macquarie~~the Master Agreement, the Schedule and the Credit Support Annex, collectively the “MRL Supply and Offtake ~~Agreements~~Agreement” ~~are~~and, ~~accounted~~together ~~for~~with bythe Shreveport Supply and Offtake Agreement, the ~~Company~~“Supply ~~similar~~and Offtake Agreements”). Pursuant to athe ~~product~~MRL ~~financing~~Supply ~~arrangement;~~and ~~therefore~~Offtake Agreement, ~~the~~Wells ~~inventories~~Fargo ~~sold~~agreed to, ~~Macquarie~~among ~~will~~other ~~continue~~things, to(a) bepurchase ~~included~~from inMRL ~~the~~renewable ~~Company~~feedstocks and finished products located at MRL’s ~~condensed~~Great ~~consolidated~~Falls ~~balance~~facility, ~~sheets~~subject ~~until~~to ~~processed~~MRL’s repurchase obligations with respect thereto, and ~~sold~~(b) provide certain financial accommodations to aMRL ~~third~~secured ~~party~~by liens on certain renewable feedstocks and finished products owned by MRL. The

For the three months ended September 30, 2023 and 2022, the Company incurred an expense of $8.5 million and $6.2 million, respectively, for financing costs related to the Supply and Offtake Agreements, which are included in interest expense in the Company’s unaudited condensed consolidated statements of operations. For the nine months ended September 30, 2023 and 2022, the Company incurred an expense of $23.1 million and $22.5 million, respectively, for financing costs related to the Supply and Offtake Agreements, which are included in interest expense in the Company’s unaudited condensed consolidated statements of operations.17

The Company has provided cash collateral of $20.6 million related to the initial purchase of the Great Falls specialty asphalt facility, Shreveport facility and Montana Renewables facility inventory to cover credit risk for future crude oil deliveries and potential liquidation risk if Macquarie exercises its rights and sells the inventory to third parties. The collateral was recorded as a reduction to the obligations.

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~~The~~MRL Supply and Offtake ~~Agreements~~Agreement ~~also~~replaced include a deferred payment arrangement (“Deferred Payment Arrangement”) whereby the Company can defer payments on just-in-time crude oil purchases from Macquarie owed under the agreements up to the value of the collateral provided (up to 90% of the collateral inventory). The deferred amounts under the Deferred Payment Arrangement bear interest at a rate equal to the Secured Overnight Financing Rate (“SOFR”) plus 3.25% per annum for the Shreveport facility and both Montana facilities. Amounts outstanding under the Deferred Payment Arrangement are included in obligations under inventory financing agreements in the CompanyMRL’s ~~condensed~~previous ~~consolidated~~inventory ~~balance sheets. Changes in the amount outstanding under the Deferred Payment Arrangement are included within cash flows from~~ financing ~~activities~~agreement inwith the Company’s unaudited condensed consolidated statements of cash flows. As of September 30, 2023 and December 31, 2022, the Company had $47.0 million and $36.0 million of deferred payments outstanding, respectively. In addition to the Deferred Payment Arrangement, Macquarie ~~advanced the Company an additional $5.0 million~~, which ~~was~~terminated ~~paid~~on ~~back~~October to3, ~~Macquarie by the Company in the first quarter of~~ 2023. ~~No amounts advanced to the Company by Macquarie remained outstanding as of September 30, 2023.~~

While title to certain inventories will reside with the counterparties to the arrangements, the Supply and Offtake Agreements are accounted for by the Company similar to a product financing arrangement; therefore, the inventories sold to the counterparties will continue to be included in the Company’s condensed consolidated balance sheets until processed and sold to a third party.

For the three months ended March 31, 2024 and 2023, the Company incurred an expense of $8.4 million and $7.0 million, respectively, for financing costs related to the Supply and Offtake Agreements, which are included in interest expense in the Company’s unaudited condensed consolidated statements of operations.

The Company’s inventory financing arrangement with Macquarie for the Company’s Shreveport facility in effect as of December 31, 2023 included a deferred payment arrangement (the “Deferred Payment Arrangement”) whereby the Company could defer payments on just-in-time crude oil purchases from Macquarie owed under the agreements up to the value of the collateral provided (90% of the collateral was inventory). The deferred amounts under the Deferred Payment Arrangement bore interest at a rate equal to the SOFR plus 3.25% per annum. Amounts outstanding under the Deferred Payment Arrangement were included in obligations under inventory financing agreements in the Company’s condensed consolidated balance sheets. Changes in the amount outstanding under the Deferred Payment Arrangement for the three months ended March 31, 2023 were included within cash flows from financing activities in the unaudited condensed consolidated statements of cash flows. As of December 31, 2023, the Company had $14.1 million of deferred payments outstanding for the inventory financing arrangement with Macquarie then in effect.

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8. Long-Term Debt

Long-term debt consisted of the following (in millions):


	~~September~~March 3031,		December 31,
	~~2023~~2024		~~2022~~2023
Borrowings under amended and restated senior secured revolving credit agreement with third-party lenders, interest payments quarterly, borrowings due January 2027, weighted average interest rates of 5.4% and 4.7% for the nine months ended September 30, 2023 and the year ended December 31, 2022, respectively.	$	71.1	$	104.0
Borrowings under amended and restated senior secured revolving credit agreement with third-party lenders, interest payments quarterly, borrowings due January 2027, weighted average interest rates of 7.5% and 6.8% for the three months ended March 31, 2024 and the year ended December 31, 2023, respectively.	$	309.8	$	136.7
Borrowings under amended secured MRL revolving credit agreement with third-party lender, interest payments quarterly, borrowings due November 2027, weighted average interest rate of 7.9% for the nine months ended September 30, 2023.		—		—
Borrowings under amended secured MRL revolving credit agreement with third-party lender, interest payments quarterly, borrowings due November 2027, weighted average interest rate of 7.4% and 6.9% for the three months ended March 31, 2024 and the year ended December 31, 2023, respectively.		22.6		13.0
Borrowings under the 2024 Secured Notes, interest at a fixed rate of 9.25%, interest payments semiannually, borrowings due July 2024, effective interest rate of 9.5% for the nine months ended September 30, 2023 and the year ended December 31, 2022.		179.0		200.0
Borrowings under the 2024 Secured Notes, interest at a fixed rate of 9.25%, interest payments semiannually, borrowings due July 2024, effective interest rate of 9.5% for the year ended December 31, 2023.		—		179.0
Borrowings under the 2025 Notes, interest at a fixed rate of 11.0%, interest payments semiannually, borrowings due April 2025, effective interest rate of 11.4% for the nine months ended September 30, 2023 and the year ended December 31, 2022.		413.5		513.5
Borrowings under the 2025 Notes, interest at a fixed rate of 11.0%, interest payments semiannually, borrowings due April 2025, effective interest rate of 11.4% for the three months ended March 31, 2024 and the year ended December 31, 2023.		413.5		413.5
Borrowings under the 2027 Notes, interest at a fixed rate of 8.125%, interest payments semiannually, borrowings due July 2027, effective interest rate of 8.3% for the nine months ended September 30, 2023 and the year ended December 31, 2022.		325.0		325.0
Borrowings under the 2027 Notes, interest at a fixed rate of 8.125%, interest payments semiannually, borrowings due July 2027, effective interest rate of 8.3% for the three months ended March 31, 2024 and the year ended December 31, 2023.		325.0		325.0
Borrowings under the 2028 Notes, interest at a fixed rate of 9.75%, interest payments semiannually, borrowings due July 2028, effective interest rate of 10.0% for the nine months ended September 30, 2023.		325.0		—
Borrowings under the 2028 Notes, interest at a fixed rate of 9.75%, interest payments semiannually, borrowings due July 2028, effective interest rate of 10.2% for the three months ended March 31, 2024 and the year ended December 31, 2023.		325.0		325.0
MRL Term Loan Credit Agreement		74.6		—
Borrowings under the 2029 Secured Notes, interest at a fixed rate of 9.25%, interest payments semiannually, borrowings due July 2029, effective interest rate of 9.4% for the three months ended March 31, 2024.		200.0		—
Shreveport terminal asset financing arrangement		52.7		58.2
MRL Term Loan Credit Agreement		74.3		74.4
MRL asset financing arrangements		388.0		370.1
Shreveport terminal asset financing arrangement		48.9		50.8
Finance lease obligations, at various interest rates, interest and principal payments monthly through June 2028		3.0		3.4
MRL asset financing arrangements		380.6		384.6
Less unamortized debt issuance costs (1)		(15.5)		(12.1)
Finance lease obligations, at various interest rates, interest and principal payments monthly through June 2028		2.7		3.0
Less unamortized discounts		(3.6)		(2.4)
Less unamortized debt issuance costs (1)		(17.4)		(16.1)
Total debt	$	1,812.8	$	1,559.7
Less unamortized discounts		(3.1)		(3.5)
Less current portion of long-term debt		204.6		20.0
Total debt	$	2,081.9	$	1,885.4
Total long-term debt	$	1,608.2	$	1,539.7
Less current portion of long-term debt		26.3		55.7
Total long-term debt	$	2,055.6	$	1,829.7

20(1) Deferred debt issuance costs are being amortized by the effective interest rate method over the lives of the related debt instruments. These amounts are net of accumulated amortization of $27.8 million and $26.6 million at March 31, 2024 and December 31, 2023, respectively.

9.25% Senior Secured First Lien Notes due 2029 (the “2029 Secured Notes”)

On March 7, 2024, the Company issued and sold $200.0 million in aggregate principal amount of 2029 Secured Notes in a private placement pursuant to Section 4(a)(2) of the Securities Act of 1933, as amended (the “Securities Act”). The 2029 Secured Notes were issued at par for net proceeds of $199.0 million, after deducting transaction expenses. The Company used the net proceeds from the private placement of the 2029 Secured Notes, together with cash on hand, to redeem all of its outstanding 9.25% Senior Secured First Lien Notes due 2024 (the “2024 Secured Notes”) and $50.0 million aggregate principal amount of its outstanding 11.00% Senior Notes due 2025 (the “2025 Notes”). The Company redeemed $50.0 million aggregate principal amount of its outstanding 2025 Notes on April 15, 2024. Interest on the 2029 Secured Notes is paid semiannually on January 15 and July 15 of each year, beginning on July 15, 2024.

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(1) Deferred debt issuance costs are being amortized by the effective interest rate method over the lives of the related debt instruments. These amounts are net of accumulated amortization of $25.4 million and $22.3 million at September 30, 2023 and December 31, 2022, respectively.

9.75% Senior Notes due 2028 (the “2028 Notes”)

On June 27, 2023, the Company issued and sold $325.0 million in aggregate principal amount of 2028 Notes, in a private placement pursuant to Section 4(a)(2) of the Securities Act to eligible purchasers at par. The Company received net proceeds of $319.1 million, after deducting the initial purchasers’ discount and offering expenses, which the Company used a portion of the net proceeds to fund offers (collectively, the “Tender Offers”) to purchase (i) any and all of its outstanding $200.0 million in aggregate principal amount of 2024 Secured Notes ~~(as defined below)~~ and (ii) up to $100.0 million in aggregate principal amount of its outstanding 2025 Notes ~~(as defined below)~~ and pay related premiums and expenses, with the remaining net proceeds to be used for general partnership purposes, including debt repayment. On June 28, 2023, in connection with the early settlement of the Tender Offers, the Company used approximately $125.5 million (excluding accrued and unpaid interest and related expenses) of the proceeds from the offering of the 2028 Notes to fund the repurchase of (i) approximately $21.0 million in aggregate principal amount of 2024 Secured Notes and (ii) $100.0 million in aggregate principal amount of the 2025 Notes and pay related premiums. Interest on the 2028 Notes is paid semiannually in arrears on January 15 and July 15 of each year, beginning on ~~July~~January 15, 2024.

8.125% Senior Notes due 2027 (the “2027 Notes”)

On January 20, 2022, the Company issued and sold $325.0 million in aggregate principal amount of 2027 Notes, in a private placement pursuant to Section 4(a)(2) of the Securities Act to eligible purchasers at par. The Company received net proceeds of $319.1 million, after deducting the initial purchasers’ discount and offering expenses, which the Company used, along with cash on hand, to fund the redemption of $325.0 million aggregate principal amount of its 2023 Senior Notes at a redemption price of par, plus accrued and unpaid interest to the redemption date of February 11, 2022. In conjunction with the redemption of the 2023 Senior Notes, the Company recorded a loss from debt extinguishment of $1.0 million, which is reflected in debt extinguishment costs in the unaudited condensed consolidated statements of operations for the nine months ended September 30, 2022. Interest on the 2027 Notes is paid semiannually in arrears on January 15 and July 15 of each year, beginning on July 15, 2022.

11.00% Senior Notes due 2025 (the “2025 Notes”) and 9.25% Senior Secured First Lien Notes due 2024 (the “2024 Secured Notes”)

The Company intends to redeem approximately $179.0 million in aggregate principal amount of 2024 Secured Notes that remain outstanding after the completion of the Tender Offer for the 2024 Secured Notes, at par, plus accrued and unpaid interest to, but not including, the redemption date. In conjunction with the repurchase of the 2024 Secured Notes and 2025 Notes in connection with the Tender Offers described above, the Company recorded a loss from debt extinguishment of $5.5 million, which is reflected in debt extinguishment costs in the unaudited condensed consolidated statements of operations for the nine months ended September 30, 2023.

Senior Notes

The ~~2024~~2025 ~~Secured~~ Notes, ~~2025~~8.125% Senior Notes, due 2027 (the “2027 Notes”), ~~and~~the 2028 Notes, and the 2029 Secured Notes (collectively, the “Senior Notes”) are subject to certain automatic customary releases, including the sale, disposition, or transfer of capital stock or substantially all of the assets of a subsidiary guarantor, designation of a subsidiary guarantor as unrestricted in accordance with the applicable indenture, exercise of legal defeasance option or covenant defeasance option, liquidation or dissolution of the subsidiary guarantor and a subsidiary guarantor ceases to both guarantee other Company debt and to be an obligor under the revolving credit facility. The Company’s operating subsidiaries may not sell or otherwise dispose of all or substantially all of their properties or assets to, or consolidate with or merge into, another company if such a sale would cause a default under the indentures governing the Senior Notes.

The indentures governing the Senior Notes contain covenants that, among other things, restrict the Company’s ability and the ability of certain of the Company’s subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Company’s common units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (vii) consolidate, merge or transfer all or substantially all of the Company’s assets; (viii) engage in transactions with affiliates and (ix) create unrestricted subsidiaries. These covenants are subject to important exceptions and qualifications. At any time when the Senior Notes are rated investment grade by either Moody’s Investors Service, Inc. (“Moody’s”) or S&P Global Ratings (“S&P”) and no Default or Event of Default, each as defined in the indentures governing the Senior Notes, has occurred and is continuing, many of these covenants will be suspended. As of March 31, 2024, the Company was in compliance with all covenants under the indentures governing the Senior Notes.

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the Company’s common units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (vii) consolidate, merge or transfer all or substantially all of the Company’s assets; (viii) engage in transactions with affiliates and (ix) create unrestricted subsidiaries. These covenants are subject to important exceptions and qualifications. At any time when the Senior Notes are rated investment grade by either Moody’s Investors Service, Inc. (“Moody’s”) or S&P Global Ratings (“S&P”) and no Default or Event of Default, each as defined in the indentures governing the Senior Notes, has occurred and is continuing, many of these covenants will be suspended. As of September 30, 2023, the Company was in compliance with all covenants under the indentures governing the Senior Notes.

MRL Asset Financing Arrangements

On August 5, 2022, Montana Renewables, LLC (“MRL”), a wholly owned subsidiary of the Company, entered into Equipment Schedule No. 2 (the “Equipment Schedule”) and an Interim Funding Agreement (the “Funding Agreement”) with Stonebriar Commercial Finance LLC (“Stonebriar”). The Equipment Schedule and the Funding Agreement each constitute a schedule under the Master Lease Agreement (the “Lease Agreement”) dated as of December 31, 2021 between MRL and Stonebriar. The Equipment Schedule provides that Stonebriar will purchase from and lease back to MRL a hydrocracker, intended to produce renewable diesel and related products, for a purchase price of $250.0 million. The Funding Agreement provides $100.0 million in financing for the design and construction of a feedstock pre-treater facility and $50.0 million for the construction of a hydrogen plant. The transactions with Stonebriar described in this paragraph are referred to herein as the “MRL asset financing arrangements.” The Company has recorded the MRL asset financing arrangements as a financial liability in the condensed consolidated balance sheets.

~~Third Amended and Restated Senior Secured Revolving Credit Facility~~20

On January 20, 2022, the Company entered into the Third Amendment to its revolving credit facility (the “Credit Facility Amendment”), which, among other changes, (a) extended the term of the revolving credit facility for five years from the date of the Credit Facility Amendment, (b) reduced aggregate commitments under the revolving credit facility to $500.0 million, which includes a FILO tranche, and (c) replaced LIBOR as a reference interest rate with a new reference interest rate based on SOFR.

The borrowing capacity at September 30, 2023, under the revolving credit facility was approximately $416.3 million. As of September 30, 2023, the Company had outstanding borrowings of $71.1 million under the revolving credit facility and outstanding standby letters of credit of $18.7 million, leaving approximately $326.5 million of unused capacity.

The revolving credit facility contains various covenants that limit, among other things, the Company’s ability to: incur indebtedness; grant liens; dispose of certain assets; make certain acquisitions and investments; redeem or prepay other debt or make other restricted payments such as distributions to unitholders; enter into transactions with affiliates; and enter into a merger, consolidation or sale of assets. Further, the revolving credit facility contains one springing financial covenant which provides that only if the Company’s availability to borrow loans under the revolving credit facility falls below an amount equal to the greater of (i) 10% of the Borrowing Base (as defined in the Credit Agreement) then in effect, and (ii) $35.0 million (which amount is subject to increase in proportion to revolving commitment increases), plus the amount of FILO loans outstanding, then the Company will be required to maintain as of the end of each fiscal quarter a Fixed Charge Coverage Ratio (as defined in the Credit Agreement) of at least 1.0 to 1.0. As of September 30, 2023, the Company was in compliance with all covenants under the revolving credit facility.

MRL Revolving Credit Agreement

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~~September 30, 2023,~~Fourth ~~under~~Amendment ~~the~~to ~~MRL~~Third ~~Revolving~~Amended ~~Credit~~and ~~Agreement~~Restated ~~was~~Senior ~~approximately~~Secured ~~$37.4 million. As of September 30, 2023, MRL had no outstanding borrowings under the MRL~~ Revolving Credit ~~Agreement.~~Facility

On January 17, 2024, the Company entered into the Fourth Amendment to its revolving credit facility (the “Credit Agreement”) governing its senior secured revolving credit facility maturing in January 2027, which provides maximum availability of credit under the revolving credit facility of $650.0 million, including a FILO tranche, subject to borrowing base limitations, and includes a $500.0 million incremental uncommitted expansion feature. Lenders under the revolving credit facility have a first priority lien on, among other things, the Company’s account receivable and inventory and substantially all of its cash (collectively, the “Credit Agreement Collateral”).

The borrowing capacity at March 31, 2024, under the revolving credit facility was approximately $521.7 million. As of March 31, 2024, the Company had outstanding borrowings of $309.8 million under the revolving credit facility and outstanding standby letters of credit of $43.6 million, leaving approximately $168.3 million of unused capacity.

The revolving credit facility contains various covenants that limit, among other things, the Company’s ability to: incur indebtedness; grant liens; dispose of certain assets; make certain acquisitions and investments; redeem or prepay other debt or make other restricted payments such as distributions to unitholders; enter into transactions with affiliates; and enter into a merger, consolidation or sale of assets. Further, the revolving credit facility contains one springing financial covenant which provides that only if the Company’s availability to borrow loans under the revolving credit facility falls below the sum of (a) the greater of (i) (x) 15% of the borrowing base then in effect at the same time that the refinery asset borrowing base component is greater than $0 and (y) 10% of the borrowing base then in effect at any time that the refinery asset borrowing base component is equal to $0 and (ii) $45.0 million (which amount is subject to certain increases) plus (b) the amount of FILO Loans outstanding, then we will be required to maintain as of the end of each fiscal quarter a Fixed Charge Coverage Ratio (as defined in the Credit Agreement) of at least 1.0 to 1.0. As of March 31, 2024, the Company was in compliance with all covenants under the revolving credit facility.

MRL Revolving Credit Agreement

On November 2, 2022, MRL entered into, as borrower, a Credit Agreement (the “MRL Revolving Credit Agreement”) with Montana Renewables Holdings LLC (“MRHL”), the parent company of MRL, and Wells Fargo Bank, National Association (“Wells Fargo”), as administrative agent and lender, which MRL Revolving Credit Agreement provides for a secured revolving credit facility in the maximum amount of $90.0 million outstanding, secured by accounts receivable, with the option to request additional commitments of up to $15.0 million, and with a maturity date of November 2, 2027. The borrowing capacity at March 31, 2024, under the MRL Revolving Credit Agreement was approximately $42.2 million. As of March 31, 2024, MRL had $22.6 million of outstanding borrowings under the MRL Revolving Credit Agreement and no outstanding standby letters of credit, leaving approximately $19.6 million of unused capacity.

MRL Term Loan Credit Agreement

On April 19, 2023, MRL and MRHL entered into a Credit Agreement (the “MRL Term Loan Credit Agreement”) with a group of financial institutions, including I Squared Capital and Delaware Trust Company, as administrative agent, that provides for a $75.0 million term loan facility with a maturity date of April 19, 2028 (the “Maturity Date”). The MRL Term Loan Credit Agreement provides for a variable interest rate based on the SOFR plus 6.0% to 7.3% per annum. The borrowings under the MRL Term Loan Credit Agreement are repayable in quarterly installments commencing on June 30, 2023, in an amount equal to 0.25% of the outstanding principal amount under the MRL Term Loan Credit Agreement as of each quarterly payment date, plus additional principal payments to the extent MRL has excess cash flows, pursuant to the terms of the MRL Term Loan Credit Agreement. The remaining borrowings under the MRL Term Loan Credit Agreement are repayable on the Maturity Date.

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Maturities of Long-Term Debt

As of ~~September~~March 3031, ~~2023~~2024, principal payments on debt obligations and future minimum rentals on finance lease obligations are as follows (in millions):


Year	Maturity
2023	$	5.6
2024	$	19.9
2024		205.2
2025		442.4
2025		442.3
2026		32.0
2026		31.9
2027		706.9
2027		445.5
2028		423.3
Thereafter		~~701~~477.49
Total	$	12,~~831~~102.94

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9. Derivatives

The Company is exposed to price risks due to fluctuations in the price of crude oil, refined products, natural gas and precious metals. The Company uses various strategies to reduce its exposure to commodity price risk. The strategies to reduce the Company’s risk utilize both physical forward contracts and financially settled derivative instruments, such as swaps, collars, options and futures, to attempt to reduce the Company’s exposure with respect to:

●

crude oil purchases and sales;

●

fuel product sales and purchases;

●

natural gas purchases;

●

precious metals purchases; and

●

fluctuations in the value of crude oil between geographic regions and between the different types of crude oil such as New York Mercantile Exchange West Texas Intermediate (“NYMEX WTI”), Light Louisiana Sweet, Western Canadian Select (“WCS”), WTI Midland, Mixed Sweet Blend, Magellan East Houston and ICE Brent.

The Company manages its exposure to commodity markets, credit, volumetric and liquidity risks to manage its costs and volatility of cash flows as conditions warrant or opportunities become available. These risks may be managed in a variety of ways that may include the use of derivative instruments. Derivative instruments may be used for the purpose of mitigating risks associated with an asset, liability and anticipated future transactions and the changes in fair value of the Company’s derivative instruments will affect its earnings and cash flows; however, such changes should be offset by price or rate changes related to the underlying commodity or financial transaction that is part of the risk management strategy. The Company does not speculate with derivative instruments or other contractual arrangements that are not associated with its business objectives.

Speculation is defined as increasing the Company’s natural position above the maximum position of its physical assets or trading in commodities, currencies or other risk bearing assets that are not associated with the Company’s business activities and objectives. The Company’s positions are monitored routinely by a risk management committee to ensure compliance with its stated risk management policy and documented risk management strategies. All strategies are reviewed on an ongoing basis by the Company’s risk management committee, which will add, remove or revise strategies in anticipation of changes in market conditions and/or its risk profiles. Such changes in strategies are to position the Company in relation to its risk exposures in an attempt to capture market opportunities as they arise.

~~The~~As of March 31, 2024 and December 31, 2023, the Company iswas obligated to repurchase crude oil, and refined products ~~and~~from ~~renewable~~its ~~feedstocks~~counterparties, ~~from~~then ~~Macquarie~~in effect, at the termination of the Supply and Offtake Agreements in certain scenarios. The Company has determined that the redemption feature on the initially recognized liability related to the Supply and Offtake Agreements is an embedded derivative indexed to commodity prices. As such, the Company has accounted for these embedded derivatives at fair value with changes in the fair value, if any, recorded in Gain (loss) on derivative instruments in the Company’s unaudited condensed consolidated statements of operations.

The Company recognizes all derivative instruments at their fair values (please read Note 10 - “Fair Value Measurements”) as either current assets or derivative liabilities or other noncurrent assets, net or other long-term liabilities in the condensed consolidated balance sheets. Fair value includes any premiums paid or received and unrealized gains and losses. Fair value does not include any amounts receivable from or payable to counterparties, or collateral provided to counterparties. Derivative asset and liability amounts with the same counterparty are netted against each other for financial reporting purposes in accordance with the provisions of our master netting arrangements.

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The following tables summarize the Company’s gross fair values of its derivative instruments, presenting the impact of offsetting derivative assets in the Company’s condensed consolidated balance sheets (in millions):


		~~September~~March 3031, ~~2023~~2024						December 31, ~~2022~~2023
				Gross		Net Amounts				Gross		Net Amounts
				Amounts		of Assets				Amounts		of ~~Liabilities~~Assets
				Offset in the		Presented				Offset in the		Presented
		Gross		Condensed		in the		Gross		Condensed		in the
		Amounts of		Consolidated		Condensed		Amounts of		Consolidated		Condensed
	Balance Sheet	Recognized		Balance		Consolidated		Recognized		Balance		Consolidated
	Location	Assets		Sheets		Balance Sheets		~~Liabilities~~Assets		Sheets		Balance Sheets
Derivative instruments not designated as hedges:
Specialty Products and Solutions segment:
Crack spread swaps	Derivative assets / Other noncurrent assets, net	$	105.35	$	~~(1.9)~~—	$	85.45	$	—11.6	$	—	$	—11.6
Montana/Renewables segment:
Total derivative instruments		$	5.5	$	—	$	5.5	$	11.6	$	—	$	11.6
Inventory financing obligation	Obligations under inventory financing agreements		8.1		(8.1)		—		—		—		—
Total derivative instruments		$	18.4	$	(10.0)	$	8.4	$	—	$	—	$	—

The following tables summarize the Company’s gross fair values of its derivative instruments, presenting the impact of offsetting derivative liabilities in the Company’s condensed consolidated balance sheets (in millions):


		~~September~~March 3031, ~~2023~~2024						December 31, ~~2022~~2023
						Net Amounts
				Gross		of Liabilities				Gross		Net Amounts
				Amounts		Presented in				Amounts		of Liabilities
				Offset in the		the				Offset in the		Presented in
		Gross		Condensed		Condensed		Gross		Condensed		the
		Amounts of		Consolidated		Consolidated		Amounts of		Consolidated		Condensed
	Balance Sheet	Recognized		Balance		Balance		Recognized		Balance		Consolidated
	Location	Liabilities		Sheets		Sheets		Liabilities		Sheets		Balance Sheets
Derivative instruments not designated as hedges:
Specialty Products and Solutions segment:
Inventory financing obligation	Other long-term liabilities / Obligations under inventory financing agreements	$	(5510.19)	$	—	$	(5510.19)	$	(3852.05)	$	—	$	(3852.05)
Crack spread swaps	Derivative liabilities / Other long-term liabilities		(1.9)		1.9		—		(50.6)		19.3		(31.3)
Total derivative instruments		$	(10.9)	$	—	$	(10.9)	$	(52.5)	$	—	$	(52.5)
Montana/Renewables segment:
Inventory financing obligation	Obligations under inventory financing agreements		(16.5)		8.1		(8.4)		(15.8)		11.3		(4.5)
Total derivative instruments		$	(73.5)	$	10.0	$	(63.5)	$	(104.4)	$	30.6	$	(73.8)

25Certain of the Company’s outstanding derivative instruments are subject to credit support agreements with the applicable counterparties which contain provisions setting certain credit thresholds above which the Company may be required to post agreed-upon collateral, such as cash or letters of credit, with the counterparty to the extent that the Company’s mark-to-market net liability, if any, on all outstanding derivatives exceeds the credit threshold amount per such credit support agreement. The majority of the credit support agreements covering the Company’s outstanding derivative instruments also contain a general provision stating that if the Company experiences a material adverse change in its business, in the reasonable discretion of the counterparty, the Company’s credit threshold could be lowered by such counterparty. The Company does not expect that it will experience a material adverse change in its business. The cash flow impact of the Company’s derivative activities are included within cash flows from operating activities in the unaudited condensed consolidated statements of cash flows.

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The Company is exposed to credit risk in the event of nonperformance by its counterparties on these derivative transactions. The Company does not expect nonperformance on any derivative instruments, however, no assurances can be provided. The Company’s credit exposure related to these derivative instruments is represented by the fair value of contracts reported as derivative assets. To manage credit risk, the Company selects and periodically reviews counterparties based on credit ratings. The Company primarily executes its derivative instruments with large financial institutions that have ratings of at least A3 and BBB+ by Moody’s and S&P, respectively. In the event of default, the Company would potentially be subject to losses on derivative instruments with mark-to-market gains. The Company requires collateral from its counterparties when the fair value of the derivatives exceeds agreed-upon thresholds in its master derivative contracts with these counterparties. No such collateral was held by the Company as of September 30, 2023 or December 31, 2022. Collateral received from counterparties is reported in other current liabilities, and collateral held by counterparties is reported in prepaid expenses and other current assets on the Company’s condensed consolidated balance sheets and is not netted against derivative assets or liabilities. Any outstanding collateral is released to the Company upon settlement of the related derivative instrument liability. As of September 30, 2023 and December 31, 2022, the Company was not required to provide collateral to its counterparties.

Certain of the Company’s outstanding derivative instruments are subject to credit support agreements with the applicable counterparties which contain provisions setting certain credit thresholds above which the Company may be required to post agreed-upon collateral, such as cash or letters of credit, with the counterparty to the extent that the Company’s mark-to-market net liability, if any, on all outstanding derivatives exceeds the credit threshold amount per such credit support agreement. The majority of the credit support agreements covering the Company’s outstanding derivative instruments also contain a general provision stating that if the Company experiences a material adverse change in its business, in the reasonable discretion of the counterparty, the Company’s credit threshold could be lowered by such counterparty. The Company does not expect that it will experience a material adverse change in its business.

The cash flow impact of the Company’s derivative activities are included within cash flows from operating activities in the unaudited condensed consolidated statements of cash flows.

Derivative Instruments Not Designated as Hedges

For derivative instruments not designated as hedges, the change in fair value of the asset or liability for the period is recorded to Gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. Upon the settlement of a derivative not designated as a hedge, the gain or loss at settlement is recorded to Gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. The Company has entered into crack spread swaps and crude oil basis swaps that do not qualify as cash flow hedges for accounting purposes. However, these instruments provide economic hedges of the purchases and sales of the Company’s natural gas, crude oil, gasoline and refined products.

The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2023 and 2022, related to its derivative instruments not designated as hedges (in millions):24


	Amount of Realized Gain (Loss)
	Recognized in Gain (Loss) on				Amount of Unrealized Gain (Loss)
	Derivative				Recognized in Gain (Loss) on Derivative
	Instruments				Instruments
	Three Months Ended September 30,				Three Months Ended September 30,
Type of Derivative	2023		2022		2023		2022
Specialty Products and Solutions segment:
Inventory financing obligation	$	—	$	—	$	(14.4)	$	5.0
Crack spread swaps		(18.0)		(11.6)		(11.7)		24.3
Montana/Renewables segment:
Inventory financing obligation		—		—		(10.2)		(1.2)
Total	$	(18.0)	$	(11.6)	$	(36.3)	$	28.1

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The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023, related to its derivative instruments not designated as hedges (in millions):


	Amount of Realized
	Loss Recognized in Gain (Loss) on				Amount of Unrealized Gain (Loss)
	Derivative				Recognized in Gain (Loss) on Derivative
	Instruments				Instruments
	~~Nine~~Three Months Ended ~~September~~March 3031,				~~Nine~~Three Months Ended ~~September~~March 3031,
Type of Derivative	~~2023~~2024		~~2022~~2023		~~2023~~2024		~~2022~~2023
Specialty Products and Solutions segment:
Inventory financing obligation	$	—(54.2)	$	—	$	~~(17~~41.1)7	$	(204.60)
Crack spread swaps		(330.38)		(2415.95)		39(6.70)		~~(21~~38.2)8
Crude oil swaps		—		(0.8)		—		—
Montana/Renewables segment:
Inventory financing obligation		—2.4		—		~~(3.8)~~—		(56.7)2
Total	$	(3352.36)	$	(2515.75)	$	1835.87	$	~~(47~~41.5)0

Derivative Positions

At ~~September~~March 3031, ~~2023~~2024, the Company had the following notional contract volumes related to outstanding derivative instruments:


		Notional Contract Volumes by
		Year of Maturity
	Total
	Outstanding
	Notional	2023	Unit of Measure
Derivative instruments not designated as hedges:
Crack spread swaps - sales	1,840,000	1,840,000	Barrels


		Notional Contract Volumes by
		Year of Maturity
	Total
	Outstanding
	Notional	2024	Unit of Measure
Derivative instruments not designated as hedges:
Crack spread swaps - sales	2,~~928~~200,000	2,~~928~~200,000	Barrels

10. Fair Value Measurements

In accordance with ASC 820, the Company uses a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. Observable inputs are from sources independent of the Company. Unobservable inputs reflect the Company’s assumptions about the factors market participants would use in valuing the asset or liability developed based upon the best information available in the circumstances. These tiers include the following:

●

Level 1 — inputs include observable unadjusted quoted prices in active markets for identical assets or liabilities

●

Level 2 — inputs include other than quoted prices in active markets that are either directly or indirectly observable

●

Level 3 — inputs include unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions

In determining fair value, the Company uses various valuation techniques and prioritizes the use of observable inputs. The availability of observable inputs varies from instrument to instrument and depends on a variety of factors including the type of instrument, whether the instrument is actively traded and other characteristics particular to the instrument. For many financial instruments, pricing inputs are readily observable in the market, the valuation methodology used is widely accepted by market participants and the valuation does not require significant management judgment. For other financial instruments, pricing inputs are less observable in the marketplace and may require management judgment.

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many financial instruments, pricing inputs are readily observable in the market, the valuation methodology used is widely accepted by market participants and the valuation does not require significant management judgment. For other financial instruments, pricing inputs are less observable in the marketplace and may require management judgment.

Recurring Fair Value Measurements

Derivative Assets and Liabilities

Derivative instruments are reported in the accompanying unaudited condensed consolidated financial statements at fair value. The Company’s derivative instruments consist of over-the-counter contracts, which are not traded on a public exchange. Substantially all of the Company’s derivative instruments are with counterparties that have long-term credit ratings of at least A3 and BBB+ by Moody’s and S&P, respectively.

Commodity derivative instruments are measured at fair value using a market approach. To estimate the fair values of the Company’s commodity derivative instruments, the Company uses the forward rate, the strike price, contractual notional amounts, the risk-free rate of return and contract maturity. Various analytical tests are performed to validate the counterparty data. The fair values of the Company’s derivative instruments are adjusted for nonperformance risk and creditworthiness of the counterparty through the Company’s credit valuation adjustment (“CVA”). The CVA is calculated at the counterparty level utilizing the fair value exposure at each payment date and applying a weighted probability of the appropriate survival and marginal default percentages. The Company uses the counterparty’s marginal default rate and the Company’s survival rate when the Company is in a net asset position at the payment date and uses the Company’s marginal default rate and the counterparty’s survival rate when the Company is in a net liability position at the payment date. As a result of applying the applicable CVA at ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023, the Company’s net assets and net liabilities changed, in each case, by an immaterial amount.

Observable inputs utilized to estimate the fair values of the Company’s derivative instruments were based primarily on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. Based on the use of various unobservable inputs, principally non-performance risk, creditworthiness of the counterparties and unobservable inputs in the forward rate, the Company has categorized these derivative instruments as Level 3. Significant increases (decreases) in any of those unobservable inputs in isolation would result in a significantly lower (higher) fair value measurement. The Company believes it has obtained the most accurate information available for the types of derivative instruments it holds. Please read Note 9 -— “Derivatives” for further information on derivative instruments.

Pension Assets

Pension assets are reported at fair value in the accompanying unaudited condensed consolidated financial statements. At ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023, the Company’s investments associated with its pension plan consisted of (i) cash and cash equivalents, (ii) fixed income bond funds, (iii) mutual equity funds, and (iv) mutual balanced funds. The fixed income bond funds, mutual equity funds, and mutual balanced funds that are measured at fair value using a market approach based on quoted prices from national securities exchanges and are categorized in Level 1 of the fair value hierarchy. The fixed income bond funds, mutual equity funds, and mutual balanced funds that are measured at fair value using a market approach based on prices obtained from an independent pricing service are categorized in Level 2 of the fair value hierarchy.

Liability Awards

Unit-based compensation liability awards are awards that are currently expected to be settled in cash on their vesting dates, rather than in equity units (“Liability Awards”). The Liability Awards are categorized as Level 1 because the fair value of the Liability Awards is based on the Company’s quoted closing unit price as of each balance sheet date.

Renewable Identification Numbers Obligation

The Company’s RINs Obligation is categorized as Level 2 and is measured at fair value using the market approach based on prices obtained from an independent pricing service. Please read Note 2 - “Summary of Significant Accounting Policies” for further information on the Company’s RINs Obligation.

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Precious Metals Obligations

The fair value of precious metals obligations is based upon unadjusted exchange-quoted prices and is, therefore, classified within Level 1 of the fair value hierarchy.

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Hierarchy of Recurring Fair Value Measurements

The Company’s recurring assets and liabilities measured at fair value were as follows (in millions):


	~~September~~March 3031, ~~2023~~2024								December 31, ~~2022~~2023
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets:
Derivative assets:
Crack spread swaps	$	—	$	—	$	85.45	$	85.45	$	—	$	—	$	—11.6	$	—11.6
Total derivative assets	$	—	$	—	$	85.45	$	85.45	$	—	$	—	$	—11.6	$	—11.6
Pension plan investments	$	243.6	$	—23.3	$	—	$	2426.69	$	263.45	$	—23.5	$	—	$	2627.40
Total recurring assets at fair value	$	243.6	$	—23.3	$	85.45	$	3332.04	$	263.45	$	—23.5	$	—11.6	$	2638.46
Liabilities:
Derivative liabilities:
Inventory financing obligation	$	—	$	—	$	(6310.59)	$	(6310.59)	$	—	$	—	$	(4252.5)	$	(4252.5)
Crack spread swaps		—		—		—		—		—		—		(31.3)		(31.3)
Total derivative liabilities	$	—	$	—	$	(10.9)	$	(10.9)	$	—	$	—	$	(52.5)	$	(52.5)
Total derivative liabilities	$	—	$	—	$	(63.5)	$	(63.5)	$	—	$	—	$	(73.8)	$	(73.8)
Precious metals obligations		(6.3)		—		—		(6.3)		(6.9)		—		—		(6.9)
RINs obligation		—		(342.8)		—		(342.8)		—		(476.8)		—		(476.8)
Liability awards		(50.4)		—		—		(50.4)		(64.2)		—		—		(64.2)
Precious metals obligations		(6.3)		—		—		(6.3)		(7.5)		—		—		(7.5)
Total recurring liabilities at fair value	$	(56.7)	$	—	$	(10.9)	$	(67.6)	$	(71.1)	$	—	$	(52.5)	$	(123.6)
Liability awards		(65.2)		—		—		(65.2)		(52.9)		—		—		(52.9)
Total recurring liabilities at fair value	$	(71.5)	$	(342.8)	$	(63.5)	$	(477.8)	$	(60.4)	$	(476.8)	$	(73.8)	$	(611.0)

The table below sets forth a summary of net changes in fair value of the Company’s Level 3 financial assets and liabilities (in millions):


	~~Nine~~Three Months Ended ~~September~~March 3031,
	~~2023~~	2024	~~2022~~	2023
Fair value at January 1,	$	(73.8)	$	(27.9)

Realized loss on derivative instruments		(33.3)		(25.7)
Fair value at January 1,	$	(40.8)	$	(73.8)
Unrealized gain (loss) on derivative instruments		18.8		(47.5)
Realized loss on derivative instruments		(52.6)		(15.5)
Settlements		33.3		25.7
Unrealized gain (loss) on derivative instruments		35.7		41.0
Fair value at September 30,	$	(55.0)	$	(75.4)
Settlements		52.6		15.5
Total gain (loss) included in net income (loss) attributable to changes in unrealized gain (loss) relating to financial assets and liabilities held as of September 30,	$	18.8	$	(47.5)
Fair value at March 31,	$	(5.1)	$	(32.8)
Total gain (loss) included in net income (loss) attributable to changes in unrealized gain (loss) relating to financial assets and liabilities held as of March 31,	$	35.7	$	41.0

Nonrecurring Fair Value Measurements

Certain non-financial assets and liabilities are measured at fair value on a nonrecurring basis and are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment.

The Company assesses goodwill for impairment annually and whenever events or changes in circumstances indicate its carrying value may not be recoverable. The fair value of the reporting units is determined using the income approach. The income approach focuses on the income-producing capability of an asset, measuring the current value of the asset by calculating the present value of its future economic benefits such as cash earnings, cost savings, corporate tax structure and product offerings. Value indications are developed by discounting expected cash flows to their present value at a rate of return that incorporates the risk-free rate for the use of funds, the expected rate of inflation and risks associated with the reporting unit. These assets would generally be classified within Level 3, in the event that the Company were required to measure and record such assets at fair value within its unaudited condensed consolidated financial statements.

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The Company periodically evaluates the carrying value of long-lived assets to be held and used, including definite-lived intangible assets and property, plant and equipment, when events or circumstances warrant such a review. Fair value is determined primarily using anticipated cash flows assumed by a market participant discounted at a rate commensurate with the risk involved and these assets would generally be classified within Level 3, in the event that the Company was required to measure and record such assets at fair value within its unaudited condensed consolidated financial statements.

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Estimated Fair Value of Financial Instruments

Cash, cash equivalents and restricted cash

The carrying value of cash, cash equivalents and restricted cash are each considered to be representative of their fair value.

Debt

The estimated fair value of long-term debt at ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023, consists primarily of senior notes. The estimated fair value of the Company’s 2024 Secured Notes ~~and~~, 2025, 2027, and 2028 Senior Notes, and 2029 Secured Notes defined as Level 2 was based upon quoted prices for identical or similar liabilities in markets that are not active. The carrying value of borrowings, if any, under the Company’s revolving credit facility, MRL revolving credit agreement, MRL asset financing arrangements, MRL term loan credit agreement, finance lease obligations and other obligations are classified as Level 3. Please read Note 8 -— “Long-Term Debt” for further information on long-term debt.

The Company’s carrying value and estimated fair value of the Company’s financial instruments, carried at adjusted historical cost, were as follows (in millions):


	~~September~~March 3031, ~~2023~~2024					December 31, ~~2022~~2023
	Level	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial Instrument:
2024 Secured Notes, 2025 Notes, 2027 Notes, and 2028 Notes	2	$	1,232.4	$	1,231.3	$	1,045.2	$	1,030.0
2024 Secured Notes, 2025 Notes, 2027 Notes, 2028 Notes, and 2029 Secured Notes	2	$	1,259.2	$	1,253.4	$	1,247.2	$	1,232.3
Revolving credit facility	3	$	71309.18	$	68306.61	$	~~104~~136.07	$	~~100~~134.94
MRL revolving credit agreement	3	$	—22.6	$	(022.6)0	$	—13.0	$	(012.6)4
MRL term loan credit agreement	3	$	74.63	$	71.76	$	—74.4		—71.6
Shreveport terminal asset financing arrangement	3	$	5248.79	$	5248.04	$	5850.28	$	5750.21
MRL asset financing arrangements	3	$	~~388~~380.06	$	~~386~~377.87	$	~~370~~384.16	$	~~368~~381.86
Finance leases and other obligations	3	$	32.07	$	32.07	$	3.40	$	3.40

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11. Earnings Per Unit

The following table sets forth the computation of basic and diluted earnings per limited partner unit (in millions, except unit and per unit data):


	Three Months Ended ~~September~~March 3031,				~~Nine Months Ended September 30,~~
	~~2023~~	2024	~~2022~~	2023	~~2023~~		~~2022~~
Numerator for basic and diluted earnings per limited partner unit:
			(As Restated)
Net income (loss)	$	99.9	$	14.6	$	94.7	$	(96.2)
Numerator for basic and diluted earnings per limited partner unit:
Net loss attributable to noncontrolling interest		(3.1)		(1.1)		(18.5)		(1.1)
Net income (loss)	$	(41.6)	$	18.6
Net income (loss) attributable to partners	$	103.0	$	15.7	$	113.2	$	(95.1)
Less:
Less:
General partner’s interest in net income (loss)		(0.8)		0.4
General partner’s interest in net income (loss)		2.1		0.3		2.3		(1.9)
Net income (loss) attributable to limited partners	$	(40.8)	$	18.2
Non-vested share based payments		0.1		0.2		0.1		—
Denominator for earnings per limited partner unit:
Net income (loss) attributable to limited partners	$	100.8	$	15.2	$	110.8	$	(93.2)
Basic weighted average limited partner units outstanding		80,352,403		79,830,671
Denominator for earnings per limited partner unit:
Effect of dilutive securities:
Basic weighted average limited partner units outstanding		80,172,810		79,384,878		80,046,930		79,277,719
Incremental units		—		109,314
Effect of dilutive securities:
Diluted weighted average limited partner units outstanding (1)		80,352,403		79,939,985
Incremental units		104,673		1,076,722		101,589		—
Limited partners’ interest basic net income (loss) per unit:
Diluted weighted average limited partner units outstanding (1)		80,277,483		80,461,600		80,148,519		79,277,719
Limited partners’ interest	$	(0.51)	$	0.23
Limited partners’ interest basic net income (loss) per unit:
Limited partners’ interest diluted net income (loss) per unit:
Limited partners’ interest	$	1(0.2651)	$	0.1923	$	~~1.38~~	$	~~(1.18)~~
Limited partners’ interest diluted net income (loss) per unit:
Limited partners’ interest	$	1.26	$	0.19	$	1.38	$	(1.18)

(1) Total diluted weighted average limited partner units outstanding excludes a de-minimis amount of potentially dilutive phantom units which would have been anti-dilutive for the nine months ended September 30, 2022.28

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(1)	Total diluted weighted average limited partner units outstanding excludes a de-minimis amount of potentially dilutive phantom units which would have been anti-dilutive for the three months ended March 31, 2024.

12. Segments and Related Information

Segment Reporting

The Company determines its reportable segments based on how the business is managed internally for the products sold to customers, including how results are reviewed and resources are allocated by the chief operating decision maker (“CODM”). The Company’s operations are managed by the CODM using the following reportable segments:

●

Specialty Products and Solutions. The Specialty Products and Solutions segment consists of our customer-focused solutions and formulations businesses, covering multiple specialty product lines, anchored by our unique integrated complex in Northwest Louisiana. In this 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.

●

Montana/Renewables. The Montana/Renewables segment is composed of our Great Falls specialty asphalt facility and our Montana Renewables facility. 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 that are distributed into renewable markets in the western half of North America. At our Montana specialty asphalt facility, we process Canadian crude oil into conventional gasoline, diesel, jet fuel and specialty grades of asphalt, with production sized to serve local markets.

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●

Performance Brands. The Performance Brands segment includes our fast-growing portfolio of high-quality, high-performing brands. In this segment, we blend, package, and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands.

●

Corporate. The Corporate segment primarily consists of general and administrative expenses not allocated to the Montana/Renewables, Specialty Products and Solutions, or Performance Brands segments.

The accounting policies of the reporting segments are the same as those described in the summary of significant accounting policies as disclosed in Note 32 - “Summary of Significant Accounting Policies,” of the ~~2022~~2023 Annual Report, except that the disaggregated financial results for the reporting segments have been prepared using a management approach, which is consistent with the basis and manner in which management internally disaggregates financial information for the purposes of assisting internal operating decisions. The Company accounts for inter-segment sales and transfers using market-based transfer pricing. The Company will periodically refine its expense allocation methodology for its segment reporting as more specific information becomes available and the industry or market changes. The Company evaluates performance based upon Adjusted EBITDA (a non-GAAP financial measure). The Company defines Adjusted EBITDA for any period as EBITDA adjusted for (a) impairment; (b) unrealized gains and losses from mark-to-market accounting for hedging activities; (c) realized gains and losses under derivative instruments excluded from the determination of net income (loss) ~~attributable to partners~~; (d) non-cash equity-based compensation expense and other non-cash items (excluding items such as accruals of cash expenses in a future period or amortization of a prepaid cash expense) that were deducted in computing net income (loss) ~~attributable to partners~~; (e) debt refinancing fees, extinguishment costs, premiums and penalties; (f) any net gain or loss realized in connection with an asset sale that was deducted in computing net income (loss) ~~attributable to partners~~; (g) amortization of turnaround costs; (h) LCM inventory adjustments; (i) the impact of liquidation of inventory layers calculated using the LIFO method; (j) RINs mark-to-market adjustments; and (k) all extraordinary, unusual or non-recurring items of gain or loss, or revenue or expense.

Reportable segment information for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023, is as follows (in millions):


	Specialty
	Products and		Performance		Montana/						Consolidated
Three Months Ended September 30, 2023	Solutions (1)		Brands (2)		Renewables		Corporate		Eliminations		Total
Sales:
External customers	$	745.7	$	75.2	$	328.5	$	—	$	—	$	1,149.4
Inter-segment sales		2.5		0.1		—		—		(2.6)		—
Total sales	$	748.2	$	75.3	$	328.5	$	—	$	(2.6)	$	1,149.4

Adjusted EBITDA	$	38.7	$	13.2	$	38.2	$	(14.6)	$	—	$	75.5
Reconciling items to net income attributable to partners:
Depreciation and amortization		19.0		2.5		21.9		0.3		—		43.7
LCM / LIFO (gain) loss		(4.4)		0.1		(0.2)		—		—		(4.5)
Interest expense		7.1		—		18.4		33.2		—		58.7
Debt extinguishment costs		—		—		—		0.3		—		0.3
Unrealized loss on derivatives		26.2		—		10.1		—		—		36.3
RINs mark-to-market gain		(118.3)		—		(55.1)		—		—		(173.4)
Other non-recurring expenses												2.4
Equity-based compensation and other items												13.8
Income tax expense												0.5
Noncontrolling interest adjustments												(5.3)
Net income attributable to partners											$	103.0

Capital expenditures	$	25.4	$	0.4	$	22.1	$	0.1	$	—	$	48.0
PP&E, net	$	375.7	$	33.2	$	1,116.0	$	2.0	$	—	$	1,526.9

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	Specialty
	Products and		Performance		Montana/						Consolidated
Three Months Ended September 30, 2022	Solutions		Brands		Renewables		Corporate		Eliminations		Total
Sales:
External customers	$	934.6	$	76.4	$	154.0	$	—	$	—	$	1,165.0
Inter-segment sales		7.1		—		—		—		(7.1)		—
Total sales	$	941.7	$	76.4	$	154.0	$	—	$	(7.1)	$	1,165.0

Adjusted EBITDA	$	131.7	$	8.5	$	11.3	$	(24.5)	$	—	$	127.0
Reconciling items to net income attributable to partners:
Depreciation and amortization		15.6		2.9		9.9		1.8		—		30.2
LCM / LIFO (gain) loss		2.1		(0.3)		(2.3)		—		—		(0.5)
Gain on impairment and disposal of assets		—		—		(0.2)		—		—		(0.2)
Interest expense		7.2		—		6.7		27.9		—		41.8
Debt extinguishment costs		—		—		38.3		2.1		—		40.4
Unrealized (gain) loss on derivatives		(29.3)		—		1.2		—		—		(28.1)
RINs mark-to-market loss		9.2		—		5.1		—		—		14.3
Other non-recurring income												(0.2)
Equity-based compensation and other items												13.0
Income tax expense												1.5
Noncontrolling interest adjustments												(0.9)
Net income attributable to partners											$	15.7

Capital expenditures	$	15.0	$	0.7	$	196.3	$	0.2	$	—	$	212.2
PP&E, net	$	374.6	$	34.0	$	917.7	$	3.1	$	—	$	1,329.4


	Specialty
	Products and		Performance		Montana/						Consolidated
Nine Months Ended September 30, 2023	Solutions (1)		Brands (2)		Renewables (3)		Corporate		Eliminations		Total
Three Months Ended March 31, 2024	Solutions		Brands		Renewables		Corporate		Eliminations		Total
Sales:
External customers	$	~~2,168~~681.56	$	~~239~~79.57	$	~~796~~244.15	$	—	$	—	$	31,~~204~~005.18
Inter-segment sales		135.10		0.21		—		—		(135.31)		—
Total sales	$	~~2,181~~686.6	$	~~239~~79.78	$	~~796~~244.15	$	—	$	(135.31)	$	31,~~204~~005.18

Adjusted EBITDA	$	~~176~~41.18	$	4113.84	$	55(14.65)	$	(5219.61)	$	—	$	~~220~~21.96
Reconciling items to net income attributable to partners:
Reconciling items to net loss:
Depreciation and amortization		5417.26		72.41		6125.34		0.83		—		~~123~~45.74
LCM / LIFO (gain) loss		(13.76)		20.2		812.94		—		—		9.40
Interest expense		207.48		~~0.1~~—		4817.30		9436.90		—		~~163~~60.78
Debt extinguishment costs		—		—		—		50.52		—		50.52
Unrealized (gain) loss on derivatives		(22.6)		—		3.8		—		—		(18.8)
Unrealized gain on derivatives		(35.7)		—		—		—		—		(35.7)
RINs mark-to-market gain		(~~146~~47.9)		—		(6923.02)		—		—		(~~215~~71.91)
Other non-recurring expenses												3560.58
Equity-based compensation and other items												22(7.53)
Income tax expense												10.42
Noncontrolling interest adjustments												~~(19~~0.3)9
Net income attributable to partners											$	113.2
Net loss											$	(41.6)

Capital expenditures	$	6514.41	$	10.43	$	~~202~~11.0	$	0.41	$	—	$	~~269~~25.25
PP&E, net	$	~~375~~368.75	$	3332.29	$	1,~~116~~082.09	$	21.07	$	—	$	1,~~526~~486.90

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	Specialty
	Products and		Performance		Montana/						Consolidated
Nine Months Ended September 30, 2022	Solutions (4) (5)		Brands		Renewables		Corporate		Eliminations		Total
Three Months Ended March 31, 2023 (As Restated)	Solutions (1)		Brands (2)		Renewables (3)		Corporate		Eliminations		Total
Sales:
External customers	$	~~2,683~~738.27	$	~~229~~78.78	$	~~774~~219.08	$	—	$	—	$	31,~~686~~037.93
Inter-segment sales		195.74		—		—		—		(195.74)		—
Total sales	$	~~2,702~~744.91	$	~~229~~78.78	$	~~774~~219.08	$	—	$	(195.74)	$	31,~~686~~037.93

Adjusted EBITDA	$	~~283~~76.30	$	1716.54	$	884.98	$	(6319.69)	$	—	$	~~326~~77.13
Reconciling items to net loss attributable to partners:
Reconciling items to net income:
Depreciation and amortization		4715.69		82.5		2818.95		50.73		—		9037.72
LCM / LIFO gain		(1.3)		(0.5)		(5.9)		—		—		(7.7)
LCM / LIFO loss		1.2		1.5		17.0		—		—		19.7
Gain on impairment and disposal of assets		—		—		(0.2)		—		—		(0.2)
Interest expense		6.5		—		12.4		30.3		—		49.2
Interest expense		24.0		1.1		25.5		85.4		—		136.0
Unrealized gain on derivatives		(34.8)		—		(6.2)		—		—		(41.0)
Debt extinguishment costs		—		—		38.3		3.1		—		41.4
RINs mark-to-market gain		(30.8)		—		(15.3)		—		—		(46.1)
Unrealized loss on derivatives		41.8		—		5.7		—		—		47.5
Other non-recurring expenses												29.5
RINs mark-to-market loss		60.0		—		32.4		—		—		92.4
Equity-based compensation and other items												9.0
Other non-recurring expenses												2.6
Income tax expense												0.5
Equity-based compensation and other items												16.6
Noncontrolling interest adjustments												0.7
Income tax expense												2.8
Net income											$	18.6
Noncontrolling interest adjustments												(0.9)
Net loss attributable to partners											$	(95.1)

Capital expenditures	$	4521.35	$	10.67	$	~~361~~115.32	$	0.31	$	—	$	~~408~~137.5
PP&E, net	$	~~374~~380.63	$	3433.07	$	~~917~~1,126.76	$	32.16	$	—	$	1,~~329~~543.42

~~(1) For the three and nine months ended September~~ 30, 2023, Adjusted EBITDA for the Specialty Products and Solutions segment included a $7.1 million and $9.5 million gain, respectively, recorded in cost of sales in the unaudited condensed consolidated statements of operations for proceeds received under the Company’s property damage insurance policy.

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(1)

For the three months ended March 31, 2023, Adjusted EBITDA for the Specialty Products and Solutions segment included a $1.1 million gain recorded in cost of sales in the unaudited condensed consolidated statements of operations for proceeds received under the Company’s property damage insurance policy.

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(2) For the three ~~and nine~~ months ended ~~September~~March 3031, 2023, Adjusted EBITDA for the Performance Brands segment included a $35.20 million ~~and $8.2 million~~ gain recorded in cost of sales in the unaudited condensed consolidated statements of operations for proceeds received under the Company’s business interruption insurance policy.

(3) For the ~~nine~~three months ended ~~September~~March 3031, 2023, Adjusted EBITDA for the Montana/Renewables segment excluded a $28.4 million charge to cost of sales in the unaudited condensed consolidated statements of operations for losses under firm purchase commitments.

(4) For the nine months ended September 30, 2022, Adjusted EBITDA for the Specialty Products and Solutions segment included a $13.9 million gain recorded to cost of sales in the unaudited condensed consolidated statements of operations for proceeds received under the Company’s business interruption insurance policy. The Company incurred business losses due to increased costs arising from a polar vortex that occurred in 2021 in northwest Louisiana. As a result, the Company filed a contingent business interruption claim. Specifically, the losses included a loss of throughput at the Shreveport refinery and additional transportation related expenses.

(5) For the nine months ended September 30, 2022, Adjusted EBITDA for the Specialty Products and Solutions segment included a $4.4 million gain recorded in cost of sales in the unaudited condensed consolidated statements of operations for proceeds received under the Company’s property damage insurance policy as a result of damages caused by a polar vortex that occurred in 2021.

Geographic Information

International sales accounted for less than ten percent of consolidated sales in the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023.

Product Information

The Company offers specialty, fuels, renewable fuels and packaged products primarily in categories consisting of lubricating oils, solvents, waxes, gasoline, diesel, jet fuel, asphalt, heavy fuel oils, renewable fuels, high-performance branded products, and other specialty and fuels products. The following table sets forth the major product category sales for each segment for the three months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023 (dollars in millions):


	Three Months Ended September 30,
	2023				2022
Specialty Products and Solutions:
Lubricating oils	$	175.8	15.3	%	$	250.4	21.5	%
Solvents		92.1	8.0	%		119.2	10.2	%
Waxes		40.1	3.5	%		50.0	4.3	%
Fuels, asphalt and other by-products		437.7	38.1	%		515.0	44.1	%
Total	$	745.7	64.9	%	$	934.6	80.1	%
Montana/Renewables:
Gasoline	$	47.9	4.2	%	$	35.2	3.0	%
Diesel		39.9	3.5	%		68.4	5.9	%
Jet fuel		5.9	0.5	%		10.1	0.9	%
Asphalt, heavy fuel oils and other		50.2	4.3	%		40.3	3.5	%
Renewable fuels		184.6	16.1	%		—	—	%
Total	$	328.5	28.6	%	$	154.0	13.3	%

Performance Brands:	$	75.2	6.5	%	$	76.4	6.6	%

Consolidated sales	$	1,149.4	100.0	%	$	1,165.0	100.0	%


	Three Months Ended March 31,
	2024				2023
Specialty Products and Solutions:
Lubricating oils	$	189.7	18.9	%	$	215.2	20.7	%
Solvents		102.4	10.2	%		106.6	10.3	%
Waxes		39.0	3.9	%		44.2	4.3	%
Fuels, asphalt and other by-products		350.5	34.8	%		372.7	35.9	%
Total	$	681.6	67.8	%	$	738.7	71.2	%
Montana/Renewables:
Gasoline	$	31.6	3.1	%	$	42.9	4.1	%
Diesel		27.9	2.8	%		32.9	3.2	%
Jet fuel		4.6	0.5	%		4.9	0.5	%
Asphalt, heavy fuel oils and other		30.1	3.0	%		20.5	2.0	%
Renewable fuels		150.3	14.9	%		118.6	11.4	%
Total	$	244.5	24.3	%	$	219.8	21.2	%

Performance Brands:	$	79.7	7.9	%	$	78.8	7.6	%

Consolidated sales	$	1,005.8	100.0	%	$	1,037.3	100.0	%

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	Nine Months Ended September 30,
	2023				2022
Specialty Products and Solutions:
Lubricating oils	$	577.2	18.0	%	$	705.2	19.1	%
Solvents		294.9	9.2	%		331.8	9.0	%
Waxes		124.5	3.9	%		144.3	3.9	%
Fuels, asphalt and other by-products		1,171.9	36.6	%		1,501.9	40.8	%
Total	$	2,168.5	67.7	%	$	2,683.2	72.8	%
Montana/Renewables:
Gasoline	$	131.6	4.1	%	$	161.6	4.4	%
Diesel		108.7	3.4	%		365.7	9.9	%
Jet fuel		16.5	0.5	%		36.3	1.0	%
Asphalt, heavy fuel oils and other		107.9	3.3	%		210.4	5.7	%
Renewable fuels		431.4	13.5	%		—	—	%
Total	$	796.1	24.8	%	$	774.0	21.0	%

Performance Brands:	$	239.5	7.5	%	$	229.7	6.2	%

Consolidated sales	$	3,204.1	100.0	%	$	3,686.9	100.0	%

Major Customers

During the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023, the Company had no customer that represented 10% or greater of consolidated sales.

Major Suppliers

During the three months ended ~~September~~March 3031, ~~2023~~2024 and ~~2022, the Company had two suppliers that supplied approximately 89.0% and 83.8%, respectively, of its crude oil supply. During the nine months ended September 30,~~ 2023 ~~and 2022~~, the Company had two suppliers that supplied approximately 9188.41% and 8494.94%, respectively, of its crude oil supply.

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13. Unrestricted Subsidiaries

As defined in the indentures governing the Company’s outstanding senior notes, an unrestricted subsidiary means MRHL, MRL and any other subsidiary of the Company, other than Calumet Finance Corp., that is designated by the Company’s general partner’s board of directors as an unrestricted subsidiary, but only to the extent that such subsidiary:

●

has no indebtedness other than non-recourse debt owing to any person other than the Company or any of its restricted subsidiaries, except to the extent permitted by the indentures of the senior notes;

●

is not party to any agreement, contract, arrangement or understanding with the Company or any restricted subsidiary of the Company unless the terms of any such agreement, contract, arrangement or other understanding are no less favorable to the Company or such restricted subsidiary than those that might be obtained at the time from persons who are not affiliates of the Company, except to the extent permitted by the indentures of the senior notes;

●

is a person with respect to which neither the Company nor any of its restricted subsidiaries has any direct or indirect obligation (a) to subscribe for additional equity interests or (b) to maintain or preserve such person’s financial condition or to cause such person to achieve any specified levels of operating results, except to the extent permitted by the indentures of the senior notes; and

●

has not guaranteed or otherwise directly or indirectly provided credit support for any indebtedness of the Company or any of its restricted subsidiaries.

36As of March 31, 2024 and December 31, 2023, respectively, MRHL and MRL were the only unrestricted subsidiaries of the Company. In accordance with the indentures governing the Company’s outstanding senior notes, the following tables set forth certain financial information (dollars in millions) of (i) the Company and its restricted subsidiaries, on a combined basis, (ii) the Company’s unrestricted subsidiaries, on a combined basis, and (iii) the Company and its subsidiaries, on a consolidated basis, in each case, as of March 31, 2024 and December 31, 2023, respectively.


	Parent
	Company and
	Restricted		Unrestricted				Consolidated
March 31, 2024	Subsidiaries		Subsidiaries		Eliminations		Total
Cash and cash equivalents	$	22.3	$	1.6	$	—	$	23.9
Accounts receivable - trade	$	253.4	$	36.0	$	—	$	289.4
Accounts receivable - other	$	28.1	$	21.5	$	—	$	49.6
Inventory	$	329.9	$	73.2	$	—	$	403.1
Prepaid expenses and other current assets	$	12.5	$	27.7	$	—	$	40.2
Property, plant and equipment, net	$	723.0	$	763.0	$	—	$	1,486.0
Other noncurrent assets, net	$	420.9	$	13.0	$	—	$	433.9
Accounts payable	$	280.9	$	410.8	$	(370.6)	$	321.1
Accrued interest payable	$	40.1	$	1.2	$	—	$	41.3
Obligations under inventory financing agreements	$	—	$	55.6	$	—	$	55.6
Other current liabilities	$	89.4	$	9.6	$	—	$	99.0
Current portion of long-term debt	$	8.9	$	17.4	$	—	$	26.3
Other long-term liabilities	$	133.1	$	2.6	$	—	$	135.7
Long-term debt	$	1,601.6	$	554.0	$	(100.0)	$	2,055.6
Redeemable noncontrolling interest	$	—	$	245.6	$	—	$	245.6
Partners’ capital (deficit)	$	(150.1)	$	(360.8)	$	(18.8)	$	(529.7)

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As of September 30, 2023 and December 31, 2022, respectively, MRHL and MRL were the only unrestricted subsidiaries of the Company. In accordance with the indentures governing the Company’s outstanding senior notes, the following tables set forth certain financial information of (i) the Company and its restricted subsidiaries, on a combined basis, (ii) the Company’s unrestricted subsidiaries, on a combined basis, and (iii) the Company and its subsidiaries, on a consolidated basis, in each case, as of September 30, 2023 and December 31, 2022, respectively.


	Parent
	Company and
	Restricted		Unrestricted				Consolidated
September 30, 2023	Subsidiaries		Subsidiaries		Eliminations		Total
December 31, 2023	Subsidiaries		Subsidiaries		Eliminations		Total
Cash and cash equivalents	$	67.13	$	70.6	$	—	$	~~13.~~7.9
Accounts receivable	$	307.4	$	40.4	$	—	$	347.8
Accounts receivable - trade	$	230.7	$	21.7	$	—	$	252.4
Inventory	$	345.0	$	102.7	$	—	$	447.7
Accounts receivable - other	$	24.8	$	9.0	$	—	$	33.8
Prepaid expenses and other current assets	$	20.7	$	28.3	$	—	$	49.0
Inventory	$	353.1	$	86.3	$	—	$	439.4
Property, plant and equipment, net	$	737.9	$	789.0	$	—	$	1,526.9
Prepaid expenses and other current assets	$	14.6	$	37.0	$	—	$	51.6
Other noncurrent assets, net	$	397.0	$	17.5	$	—	$	414.5
Property, plant and equipment, net	$	731.7	$	774.6	$	—	$	1,506.3
Accounts payable	$	307.4	$	283.9	$	(249.2)	$	342.1
Other noncurrent assets, net	$	436.9	$	13.4	$	—	$	450.3
Accrued interest payable	$	40.2	$	1.0		—		41.2
Accounts payable	$	282.4	$	333.3	$	(293.7)	$	322.0
Obligations under inventory financing agreements	$	166.1	$	71.8	$	—	$	237.9
Accrued interest payable	$	47.8	$	0.9	$	—	$	48.7
Other current liabilities	$	73.0	$	12.2	$	—	$	85.2
Obligations under inventory financing agreements	$	126.0	$	64.4	$	—	$	190.4
Current portion of long-term debt	$	187.8	$	16.8	$	—	$	204.6
Other current liabilities	$	104.5	$	27.0	$	—	$	131.5
Other long-term liabilities	$	53.7	$	3.8	$	—	$	57.5
Current portion of long-term debt	$	38.8	$	16.9	$	—	$	55.7
Long-term debt	$	1,167.0	$	541.2	$	(100.0)	$	1,608.2
Other long-term liabilities	$	50.6	$	3.0	$	—	$	53.6
Redeemable noncontrolling interest	$	—	$	250.0	$	—	$	250.0
Long-term debt	$	1,381.0	$	548.7	$	(100.0)	$	1,829.7
Partners’ capital (deficit)	$	(233.6)	$	(195.2)	$	(18.8)	$	(447.6)
Redeemable noncontrolling interest	$	—	$	245.6	$	—	$	245.6
Partners’ capital (deficit)	$	(174.3)	$	(297.2)	$	(18.8)	$	(490.3)

The following table sets forth certain financial information of the Company’s unrestricted subsidiaries, on a combined basis, for the periods presented (in millions):


	~~Parent~~Three Months Ended March 31,
	~~Company and~~2024		2023
	~~Restricted~~		~~Unrestricted~~				~~Consolidated~~
December 31, 2022	Subsidiaries		Subsidiaries		Eliminations		Total
Sales	$	150.3	$	118.6
Cash and cash equivalents	$	9.4	$	25.8	$	—	$	35.2
Cost of sales		184.0		170.6
Accounts receivable	$	259.8	$	8.2	$	—	$	268.0
Gross profit (loss)		(33.7)		(52.0)
Inventory	$	370.1	$	127.9	$	—	$	498.0
Operating costs and expenses:
Prepaid expenses and other current assets	$	13.2	$	6.0	$	—	$	19.2
General and administrative		6.5		3.7
Property, plant and equipment, net	$	760.7	$	721.3	$	—	$	1,482.0
Other operating expense		1.5		3.0
Other noncurrent assets, net	$	428.8	$	10.6	$	—	$	439.4
Operating loss		(41.7)		(58.7)
Accounts payable	$	307.6	$	265.6	$	(130.8)	$	442.4

Obligations under inventory financing agreements	$	158.2	$	63.6	$	—	$	221.8
Other income (expense):
Other current liabilities	$	100.8	$	13.7	$	—	$	114.5
Interest expense		(24.6)		(13.0)
Current portion of long-term debt	$	8.2	$	11.8	$	—	$	20.0
Gain on derivative instruments		2.4		4.2
Other long-term liabilities	$	59.0	$	1.2	$	—	$	60.2
Other income		0.3		—
Long-term debt	$	1,183.3	$	356.4	$	—	$	1,539.7
Total other expense		(21.9)		(8.8)
Redeemable noncontrolling interest	$	—	$	250.0	$	—	$	250.0
Net loss	$	(63.6)	$	(67.5)
Partners’ capital (deficit)	$	(456.4)	$	(62.5)	$	(18.8)	$	(537.7)

For the three months ended September 30, 2023, the Company’s unrestricted subsidiaries had revenue of $184.6 million, operating costs of $164.1 million, which was exclusive of depreciation expense of $11.7 million, selling, general and administrative expense of $5.8 million, interest expense of $22.6 million, unrealized loss on derivative instruments of $4.5 million, other income of $0.6 million and net loss attributable to noncontrolling interest of $3.1 million. For the three months ended September 30, 2022, the Company’s unrestricted subsidiaries had tolling revenue of $20.3 million, operating costs of $4.6 million, which was exclusive of depreciation expense of $3.8 million, interest expense of $7.1 million, and loss on debt extinguishment of $38.3 million.

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For the nine months ended September 30, 2023, the Company’s unrestricted subsidiaries had revenue of $431.4 million, operating costs of $452.3 million, which was exclusive of depreciation expense of $30.7 million, selling, general and administrative expense of $15.1 million, other operating expense of $4.0 million, interest expense of $59.5 million, unrealized loss on derivative instruments of $3.2 million, other income of $0.7 million and net loss attributable to noncontrolling interest of $18.5 million. For the nine months ended September 30, 2022, the Company’s unrestricted subsidiaries had tolling revenue of $63.5 million, operating costs of $18.5 million, which was exclusive of depreciation expense of $11.3 million, interest expense of $29.4 million, and loss on debt extinguishment of $38.3 million.

14. Redeemable Noncontrolling Interest

On August 5, 2022 (the “Closing Date”), MRHL issued and sold 12,500,000 preferred units (“Preferred Units”) in MRHL to an affiliate of Warburg Pincus LLC for $250.0 million for an immediate cash payment of $200.0 million and the agreement to pay the remaining $50.0 million in cash not later than October 3, 2022 (the “Deferred Purchase Price”) in exchange for a Percentage Interest of 14.2% in MRHL. The Company received the cash payment for the Deferred Purchase Price on October 3, 2022. The Preferred Units are not interest bearing and carry certain minimum return thresholds.

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Holders of the Preferred Units are entitled to receive a preferred return equal to the greater of (i) an internal rate of return, or IRR (as defined in the Second Amended and Restated Limited Liability Company Agreement of MRHL (the “Second A&R LLC Agreement”), equal to 8.0% and (ii) a multiple on invested capital, or MOIC (as defined in the Second A&R LLC Agreement), initially equal to 1.35 and increasing by 0.01 each anniversary of the Closing Date up to a maximum MOIC equal to 1.40 on or after the fifth anniversary of the Closing Date (the “Preferred Return”). Pursuant to the Second A&R LLC Agreement, MRHL is required to distribute all Available Cash (as defined in the Second A&R LLC Agreement), to the members of MRHL (the “Members”) in the following priority: (i) 37.5% to the holders of the Preferred Units and 62.5% to all other Members pro rata based on their Percentage Interests (as defined in the Second A&R LLC Agreement) until the holders of the Preferred Units receive the Preferred Return and (ii) thereafter, 100.0% to the Members pro rata based on their Percentage Interests. Additionally, pursuant to the Second A&R LLC Agreement the Company is required to make distributions to the members sufficient to enable them to pay, on a quarterly basis, federal, state and local taxes arising from the allocations made to such members. Further, such distributions are determined by the Company and shall be made within thirty (30) days after the close of each applicable quarter. Any tax liability distributions shall be treated as an advance against, and shall reduce the amount of, the next distribution that the members would otherwise receive pursuant to the agreement.

At any time following the fifth anniversary of the Closing Date, if MRHL has not had an Initial Public Offering or Change of Control (each as defined in the Second A&R LLC Agreement), Warburg has the right to initiate an Initial Public Offering or Change of Control transaction pursuant to the terms of the Second A&R LLC Agreement. Upon the closing of a Qualified Initial Public Offering (as defined in the Second A&R LLC Agreement), each of MRHL and Warburg have the right to elect to convert all (but not less than all) of the Preferred Units (i) first by MRHL paying each holder of Preferred Units an amount in cash equal to such holder’s Preferred Return (to the extent not already paid) and (ii) thereafter, the Preferred Units automatically convert into the same number of common units of MRHL and will be entitled to participate in any distributions of Available Cash to the Members in proportion to their respective Percentage Interests. The Second A&R LLC Agreement also provides certain drag-along rights in connection with a Change of Control, subject to a minimum preferred return requirement for certain transactions that are consummated before the third anniversary of the Closing Date.

The redeemable noncontrolling interest in MRHL is reflected as temporary equity in the condensed consolidated balance sheets due to the redemption features described above and included a balance of $~~250~~245.06 million as of ~~September~~March 3031, 2024 and December 31, 2023., ~~The~~respectively, ~~Company~~which represents the amount recorded for the Preferred Units at their issuance date fair value, net of issuance costs. ~~We recorded an adjustment for the $18.5 million net loss attributable to noncontrolling interest to accrete the carrying amount to redemption value as of September 30, 2023.~~ As of the reporting date, there are no triggering, change of control, early redemption or monetization events that are probable that would require us to revalue the Preferred Units.

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The changes in our redeemable noncontrolling interest in MRHL from December 31, 2022 to September 30, 2023 were as follows (in millions).


	Redeemable Noncontrolling Interest
Balance at December 31, 2022	$	250.0
Net loss attributable to noncontrolling interest		(18.5)
Adjustment to ASC 480 redemption value		18.5
Balance at September 30, 2023	$	250.0

15. Subsequent Events

As of ~~November~~May 37, ~~2023~~2024, the fair value of the Company’s derivative instruments has ~~changed~~increased by approximately $138.06 million subsequent to ~~September~~March 3031, ~~2023~~2024.

On October 3, 2023, MRL and Wells Fargo Commodities, LLC (“Wells Fargo”) entered into (i) an ISDA 2002 Master Agreement (the “Master Agreement”), (ii) a Schedule to the ISDA 2002 Master Agreement (the “Schedule”), (iii) a Credit Support Annex to the Schedule to the ISDA 2002 Master Agreement (the “Credit Support Annex”), and (iv) a Renewable Fuel and Feedstock Repurchase Master Confirmation (the “Master Confirmation” and, together with the Master Agreement, the Schedule and the Credit Support Annex, the “Facility Documents”). Pursuant to the Facility Documents, Wells Fargo agreed to, among other things, (a) purchase from MRL renewable feedstocks and finished products located at MRL’s Great Falls, Montana refinery, subject to MRL’s repurchase obligations with respect thereto, and (b) provide certain financial accommodations to MRL secured by liens on certain renewable feedstocks and finished products owned by MRL. Wells Fargo agreed to provide MRL total liquidity of up to $120.0 million pursuant to the Facility Documents, subject to the conditions specified in the Facility Documents.

On September 26, 2023, MRL and Macquarie Energy North America Trading Inc. entered into a Fourth Amendment to Supply and Offtake Agreement, dated September 26, 2023 (the “S&O Agreement”), pursuant to which the termination date of the S&O Agreement was extended from September 30, 2023 to October 3, 2023. The S&O Agreement terminated on October 3, 2023. The financing arrangements under the Wells Facility Documents replaced the arrangements under the Macquarie S&O Agreement.

3935

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

The historical unaudited condensed consolidated financial statements included in this Quarterly Report reflect all of the assets, liabilities and results of operations of Calumet Specialty Products Partners, L.P. (“Calumet,” the “Company,” “we,” “our,” or “us”). The following discussion analyzes the financial condition and results of operations of the Company for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024. Unitholders should read the following discussion and analysis of our financial condition and results of operations in conjunction with our ~~2022~~2023 Annual Report and our historical unaudited condensed consolidated financial statements and notes included elsewhere in this Quarterly Report.

Overview

We manufacture, formulate and market a diversified slate of specialty branded products and renewable fuels to customers across a broad range of consumer-facing and industrial markets. We are headquartered in Indianapolis, Indiana and operate twelve facilities throughout North America.

Our operations are managed using the following reportable segments: Specialty Products and Solutions; Performance Brands; Montana/Renewables; and Corporate. For additional information, see Note 12 -— “Segments and Related Information” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements.” In our Specialty Products and Solutions segment, we manufacture and market a wide variety of solvents, waxes, customized lubricating oils, white oils, petrolatums, gels, esters, and other products. Our specialty products are sold to domestic and international customers who purchase them primarily as raw material components for consumer-facing and industrial products. In our Performance Brands segment, we blend, package and market high performance products through our Royal Purple, Bel-Ray, and TruFuel brands. Our Montana/Renewables segment is comprised of two facilities — renewable fuels and specialty asphalt. At our Great Falls renewable fuels facility, we process a variety of geographically advantaged renewable feedstocks into renewable diesel, sustainable aviation fuel, renewable hydrogen, renewable natural gas, renewable propane, and renewable naphtha that are distributed into renewable markets in the western half of North America. At our Montana specialty asphalt facility, we process Canadian crude oil into conventional gasoline, diesel, jet fuel and specialty grades of asphalt, with production sized to serve local markets. Our Corporate segment primarily consists of general and administrative expenses not allocated to the Specialty Products and Solutions, Performance Brands or Montana/Renewables segments.

Recent Developments

OnAs ~~November~~previously disclosed, on February 9, ~~2023~~2024, we entered into a ~~Partnership~~Conversion ~~Restructuring~~ Agreement (the “~~Restructuring~~Conversion Agreement”) with Calumet, Inc. (“New Calumet”), Calumet Merger Sub I LLC, a wholly owned subsidiary of New Calumet (“Merger Sub I”), Calumet Merger Sub II LLC, a wholly owned subsidiary of New Calumet (“Merger Sub II”), Calumet GP, LLC, our general partner, and The Heritage Group and the other owners of our general partner (collectively, the “Sponsor Parties”) to effectuate a corporate transition of the Company to aNew ~~new~~Calumet ~~Delaware~~that ~~corporation~~would (“result in the Company and our general partner becoming subsidiaries of New Calumet (the “Conversion”).

~~Pursuant~~On April 17, 2024, we entered into that certain First Amendment to Conversion Agreement (the ~~Restructuring~~“Conversion Agreement Amendment”), by and among the ~~transaction~~Company, ~~documents~~New toCalumet, beMerger ~~entered~~Sub ~~into~~I, inMerger ~~connection~~Sub ~~therewith~~II, at our general partner and the ~~closing~~Sponsor ofParties, to reflect certain changes in the ~~transactions~~forms ~~contemplated~~of by(i) the ~~Restructuring~~Amended ~~Agreement~~and Restated Certificate of Incorporation of New Calumet, (ii) the ~~“Corporate~~Amended ~~Reorganization”~~and Restated Bylaws of New Calumet and (iii) the Stockholders Agreement with The Heritage Group, ~~among~~in ~~other~~each ~~things:~~case, attached as an exhibit to the Conversion Agreement.

~~●each~~The ~~common~~Board ~~unit~~of ~~representing~~Directors aof ~~limited~~our ~~partnership~~general ~~interest~~partner in(the “Board”) has unanimously approved the ~~Company~~terms ~~will~~of bethe ~~exchanged~~Conversion ~~for~~Agreement ~~one~~Amendment ~~share~~and the transactions contemplated thereby. The Board approved the Conversion Agreement Amendment following the recommendation and special approval of ~~New~~the ~~Calumet’s~~Conflicts ~~common~~Committee ~~stock~~of ~~(“Common~~the ~~Stock”);~~Board.

●all equity interests in our general partner (which currently owns all of our incentive distribution rights and our 2.0% General Partner interest in the Company) will be exchanged for 5.5 million shares of Common Stock and warrants to purchase 2.0 million shares of Common Stock, each exercisable for one share of Common Stock at an exercise price of $20.00 per share and expiring three years from the date of issuance, which shares and warrants will be issued to the owners of our general partner;36

●as a result of the Corporate Reorganization, our general partner will become a wholly owned subsidiary of New Calumet, and its incentive distribution rights and 2.0% General Partner interest will be cancelled,

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~~and~~The foregoing description of the ~~Company~~Conversion ~~will~~Agreement ~~become~~Amendment ais ~~wholly~~not ~~owned~~complete ~~subsidiary~~and ofis ~~New~~qualified ~~Calumet;~~in its entirety by reference to the ~~New~~complete ~~Calumet~~text ~~Common~~of ~~Stock~~the ~~will~~Conversion ~~continue~~Agreement Amendment, a copy of which is included as Exhibit 2.2 to ~~trade~~this Quarterly Report on ~~Nasdaq~~Form 8-K and is incorporated herein by reference.

First Quarter 2024 Update

For additional information, please read our Current Report on Form 8-K filed with the Securities and Exchange Commission on November 9, 2023. Please also read Part II, Item 1A “Risk Factors—The Corporate Reorganization is subject to conditions, including some conditions that may not be satisfied on a timely basis, if at all. Failure to complete the Corporate Reorganization, or significant delays in completing the Corporate Reorganization, could negatively affect our business and financial results and the price of our common units or, following the consummation of the Corporate Reorganization, future business and financial results and the price of the common stock.”

Third Quarter 2023 Update

Outlook and Trends

During the ~~third~~first quarter of ~~2023~~2024, our business continued to benefit from aan ~~healthy~~above mid-cycle margin environment in our Specialty Products and Solutions and Performance Brands segments. Demand for our products in these businesses remained ~~healthy~~strong ~~across~~in ~~most~~comparison ofto ~~the~~historical ~~enterprise,~~averages and we ~~expect~~continue to leverage the benefits of our fully integrated specialty business in this market. As expected, margins continue to ~~continue~~slowly normalize relative to bethe record highs experienced in the second half of 2022 and early 2023, but remain elevated above ~~historical~~mid-cycle ~~averages~~levels, which we expect to continue for the remainder of the year. WeFurther, we believe low unemployment, and stabilizing raw material and packaging costs, ~~and~~point ~~lower~~to ~~than~~a ~~normal~~continuation ~~industry~~of ~~inventories~~healthy ~~point~~demand tofor athe ~~continuation~~majority of ~~this~~our ~~trend~~products. While the risk of recession and inflation continue to be monitored, our plants and the industry are expected to operate at high rates to meet market demand.

~~Our~~In ~~Specialty~~our ~~Products~~Montana/Renewables ~~and Solutions~~ segment, ~~continues~~we continue to ~~find~~see ~~itself~~strong indemand anfor ~~above~~our ~~mid-cycle~~renewable ~~margin~~fuel ~~environment~~products. ~~Market~~We ~~demand~~maintain isour ~~relatively~~outlook ~~high~~of ~~compared~~strong todemand ~~historical~~for ~~averages,~~renewable ~~and~~fuel weproducts, ~~continue~~including tothose ~~leverage~~we ~~the~~produce ~~benefits~~at of our ~~fully~~Montana ~~integrated~~Renewables ~~specialty~~facility. ~~business~~We inbelieve ~~this~~demand ~~market.~~for Asrenewable ~~expected,~~fuel ~~margins~~products ~~continued~~will toonly ~~slowly~~continue ~~normalize relative~~ to ~~record~~grow ~~highs~~as ~~experienced~~a inresult of the ~~second~~rapid ~~half~~expansion of ~~2022.~~corporate Atdecarbonization ~~our~~targets, ~~Montana~~broad ~~Renewables~~sustainability ~~facility~~initiatives, weand ~~identified~~governmental amandates ~~leak~~and inincentives ~~the~~that ~~steam~~have ~~recovery~~been ~~system~~passed ~~within~~or ~~the~~announced ~~renewable~~by ~~hydrogen~~national, ~~plant~~state, ~~which~~and ~~limited~~provincial ~~throughput~~jurisdictions ~~during~~across the ~~quarter~~globe. WeIn ~~are~~light ~~in the process~~ of ~~replacing~~ the ~~steam~~global ~~drum~~decarbonization initiatives, ~~which~~forecasts isof ~~expected~~future toavailability bestill ~~completed~~fall ~~during~~short ~~the fourth quarter. During this period~~ of ~~steam~~the ~~system~~necessary ~~repairs,~~emissions ~~MRL~~reductions ~~will~~that ~~opportunistically~~would ~~pull~~be ~~forward~~required ~~regularly~~to ~~scheduled~~reach ~~maintenance~~established ~~into~~net-zero ~~November~~goals, ~~which~~as ~~was~~supply ~~previously~~does ~~scheduled~~not ~~for~~exist ~~early 2024~~yet. ~~The~~For example, our Montana Renewables facility is ~~expected~~one toof ~~continue~~the toonly ~~operate~~facilities atin ~~reduced~~Norh ~~throughput~~America ~~until~~capable ~~the~~of ~~system~~SAF ~~returns~~production toat ~~normal~~scale ~~operations. Results~~ in ~~our~~North ~~Performance~~America ~~Brands~~today. ~~segment~~We ~~continued~~believe tothat ~~trend~~our ~~better~~position ~~versus the prior year~~ as ~~input~~a ~~and~~first-mover ~~packaging~~makes ~~costs~~us ~~have~~the ~~stabilized,~~key ~~price~~producer ~~increases~~for ~~from~~potential ~~previous~~offtake ~~periods~~partners ~~have~~to ~~largely~~help ~~held,~~them ~~and~~reach ~~industrial~~their ~~volume~~announced ~~demand continues to grow~~targets.

As we have experienced in the past several years, our integrated business model and diversified product portfolio provides an advantaged response to changing market conditions. While we are not immune to the impacts of an economic downturn, we believe our specialty business is well positioned to withstand one.

As we saw during 2020 with COVID-19 and the start of the global pandemic, our integrated business model and diversified product portfolio provides an advantaged response to changing market conditions. While we are not immune to the impacts of an economic downturn, we believe our specialty business is well positioned to withstand one.

Contingencies

For a summary of litigation and other contingencies, please read Note 6 -— “Commitments and Contingencies” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements.” Based on information available to us at the present time, we do not believe that any liabilities beyond the amounts already accrued, which may result from these contingencies, will have a material adverse effect on our liquidity, financial condition or results of operations.

Financial Results

We reported a net ~~income~~loss of $9941.96 million in the ~~third~~first quarter ~~2023~~2024 versus net income of $1418.6 million in the ~~third~~first quarter ~~2022 and net income attributable to partners of $103.0 million in the third quarter~~ 2023 ~~versus net income attributable to partners of $15~~.7 ~~million in the third quarter 2022.~~ We reported Adjusted EBITDA (as defined in Note 12 -— “Segments and Related Information” under Part I, Item 1 “Financial Statements -— Notes to Unaudited Condensed Consolidated Financial Statements”) of $7521.56 million in the ~~third~~first quarter ~~2023~~2024 versus $~~127~~77.3 million in the first quarter 2023. We used cash from operating activities of $94.0 million in the ~~third~~first quarter 2024 versus using cash from operating activities of $26.7 million in the first quarter of 2023.

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2022. We generated cash from operating activities of $45.2 million in the third quarter 2023 versus generating cash from operating activities of $63.9 million in the third quarter of 2022.

Please read Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Non-GAAP Financial Measures” for a reconciliation of EBITDA, Adjusted EBITDA and Distributable Cash Flow to Net income (loss), our most directly comparable financial performance measure calculated and presented in accordance with U.S. generally accepted accounting principles (“GAAP”).

Specialty Products and Solutions segment Adjusted EBITDA was $3841.78 million in the ~~third~~first quarter ~~2023~~2024 versus $~~131~~76.70 million in the ~~third~~first quarter ~~2022~~2023. Compared to the ~~third~~first quarter of ~~2022~~2023, Specialty Products and Solutions ~~third~~first quarter ~~2023~~2024 segment Adjusted EBITDA was unfavorably impacted by lower throughput volumes as a result of required maintenance completed at our Shreveport facility during the quarter, which resulted in a loss of approximately 300,000 barrels of lube oil and wax sales. The specialties and fuels margin environments continue to slowly regress from record highs, but remain strong compared to historical averages and continue to benefit our business.

Montana/Renewables segment Adjusted EBITDA was $38.2 million in the third quarter 2023 versus $11.3 million in the third quarter 2022. Our current quarter results were favorably impacted by higher sales volumes due to the absence of the turnaround that was completed at our Montana specialty asphalt facility in the prior year comparative period. Our current quarter results were unfavorably impacted due to higher material costs, primarily as it related to higher priced pre-treated feedstocks to support the start-up of the feedstock pre-treatment and SAF units. As a result of commissioning these units, we have continued progress to rotate our current feedstock mix from treated feeds that are being reduced from safety stock to advantaged untreated feedstocks, which is expected to unlock the advantaged price and feedstock optionality we have in Montana.37

~~Performance~~Table ~~Brands segment Adjusted EBITDA was $13.2 million in the third quarter 2023 versus $8.5 million in the third quarter 2022. Compared to the third quarter~~ of 2022, Performance Brands segment Adjusted EBITDA was favorably impacted by an increase in net unit margins as a result of input costs stabilizing in our branded and consumer markets and an increase in industrial volumes. The segment also benefited from a partial payout of our ongoing business interruption claims and received a $3.2 million insurance payment during the current quarter.Contents

~~Total~~segment ~~Corporate~~Adjusted ~~costs~~EBITDA ~~represented~~was unfavorably impacted by lower throughput volumes as a ~~loss~~result of ~~$14.6~~a ~~million~~planned ofturnaround ~~Adjusted~~at ~~EBITDA~~our inShreveport ~~the~~facility ~~third~~during the quarter. ~~2023~~The ~~versus~~turnaround aat ~~loss~~our ofShreveport ~~$24.5~~facility ~~million~~was ofsuccessfully ~~Adjusted~~completed ~~EBITDA~~on time and on budget. Current period results in ~~the~~our ~~third~~fuels ~~quarter~~business ~~2022~~were ~~due~~unfavorably toimpacted ~~lower~~by ~~labor~~weak asphalt margins, which was the result of seasonality and ~~benefits~~a ~~related~~run-up ~~expenses~~in crude prices.

Montana/Renewables segment Adjusted EBITDA was a loss of $14.5 million in the first quarter 2024 versus $4.8 million in the first quarter 2023. Our current quarter results were unfavorably impacted by higher material costs, primarily as it related to processing higher priced pre-treated feedstocks purchased prior to the summer 2023 slowdown related to a steam system issue. During the current quarter, our Montana Renewables business showed sequential month over month improvements in operational and financial performance. Progression of operational milestones throughout the current quarter have allowed us to process an overhang of the old and expensive pre-treated feedstock inventory. Results were also impacted by a seasonally weak asphalt and gas market in Montana exacerbated by a rapid run-up in WCS prices and higher operating expenses as a result of a utility surcharge during the extreme January temperatures.

Performance Brands segment Adjusted EBITDA was $13.4 million in the first quarter 2024 versus $16.4 million of Adjusted EBITDA in the first quarter 2023, which included a $5.0 million favorable benefit for the receipt of an insurance claim. Results in our Performance Brands segment were up driven by strong volume growth across high performance products slightly offset by weakness in retail channels.

Total Corporate costs represented a loss of $19.1 million of Adjusted EBITDA in the first quarter 2024 versus a loss of $19.9 million of Adjusted EBITDA in the first quarter 2023 due to lower labor and benefits related expenses.

Liquidity Update

As of ~~September~~March 3031, ~~2023~~2024, we had total liquidity of $~~377~~211.68 million comprised of $1323.79 million of unrestricted cash and $~~363~~187.9 million of availability under our credit facilities. As of ~~September~~March 3031, ~~2023~~2024, our revolving credit facilities had a $~~453~~563.79 million borrowing base, $1843.76 million in outstanding standby letters of credit and $71332.14 million of outstanding borrowings. We believe we will continue to have sufficient liquidity from cash on hand, projected cash flow from operations, borrowing capacity and other means by which to meet our financial commitments, debt service obligations, contingencies, and anticipated capital expenditures for at least the next 12 months. Please read Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations -— Liquidity and Capital Resources” for additional information.

Renewable Fuel Standard Update

Along with the broader refining industry, we remain subject to compliance costs under the RFS unless or until we receive a small refinery exemption from the EPA, which we have historically received. Administered by the EPA, the RFS provides annual requirements for the total volume of renewable transportation fuels that are mandated to be blended into finished transportation fuels. If a refiner does not meet its required annual Renewable Volume Obligation, the refiner can purchase blending credits in the open market, referred to as RINs.

During the ~~third~~first quarter ~~2023~~2024, we recorded a gain of $~~157~~64.35 million for RINs, as compared to ana ~~expense~~gain of $3732.31 million for RINs in the ~~third~~first quarter ~~2022~~2023. Our gross RINs Obligation, which includes RINs that are required to be secured through either our own blending or through the purchase of RINs in the open market, is spread across four compliance categories (D3, D4, D5 and D6). The gross RINs obligations may be satisfied by our own renewables blending, RIN purchases, or receipt of small refinery exemptions.

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through either our own blending or through the purchase of RINs in the open market, is spread across four compliance categories (D3, D4, D5 and D6). The gross RINs obligations may be satisfied by our own renewables blending, RIN purchases, or receipt of small refinery exemptions.

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

See Note 2 - “Summary of Significant Accounting Policies” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report for further information on the Company’s RINs obligation.38

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See Note 2 — “Summary of Significant Accounting Policies” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report for further information on the Company’s RINs obligation.

Unrestricted Subsidiaries

See Note 13 -— “Unrestricted Subsidiaries” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report for further information regarding certain financial information of our unrestricted subsidiaries.

Key Performance Measures

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

Our primary raw materials are crude oil, renewable feedstocks, and other specialty feedstocks, and our primary outputs are specialty consumer-facing and industrial products, specialty branded products, fuel products, and renewable fuel products. The prices of crude oil, specialty products, fuel products, and renewable fuel products are subject to fluctuations in response to changes in supply, demand, market uncertainties and a variety of factors beyond our control. We monitor these risks and from time-to-time enter into derivative instruments designed to help mitigate the impact of commodity price fluctuations on our business. The primary purpose of our commodity risk management activities is to economically hedge our cash flow exposure to commodity price risk. We also may hedge when market conditions exist that we believe to be out of the ordinary and particularly supportive of our financial goals. We enter into derivative contracts for future periods in quantities that do not exceed our projected purchases of crude oil and natural gas and sales of fuel and renewable fuel products. Please read Note 9 — “Derivatives” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

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

●

sales volumes;

●

segment gross profit;

●

segment Adjusted gross profit;

●

segment Adjusted EBITDA; and

●

selling, general and administrative expenses.

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

43Segment gross profit. Specialty Products and Solutions, Montana/Renewables and Performance Brands products gross profit are important measures of profitability of our segments. We define gross profit as sales less the cost of crude oil and other feedstocks, LCM/LIFO adjustments, and other production-related expenses, the most significant portion of which includes labor, plant fuel, utilities, contract services, maintenance, transportation, RINs, depreciation and amortization and processing materials. We use gross profit as an indicator of our ability to manage margins in our business over the long-term. The increase or decrease in selling prices typically lags behind the rising or falling costs, respectively, of feedstocks throughout our business. Other than plant fuel, RINs mark-to-market adjustments, and LCM/LIFO adjustments, production

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~~Higher~~related ~~volumes~~expenses ~~improve~~generally ~~profitability~~remain ~~both~~stable ~~through~~across ~~the~~broad ~~spreading~~ranges ofbut ~~fixed~~can ~~costs~~fluctuate ~~over~~depending ~~greater~~on ~~volumes~~maintenance ~~and~~activities ~~the~~performed ~~additional~~during ~~gross~~a ~~profit~~specific ~~achieved on the incremental volumes~~period.

Segment Adjusted gross profit. Specialty Products and Solutions, Montana/Renewables and Performance Brands products segment Adjusted gross profit ~~are important~~ measures ofare ~~profitability~~useful ofas ~~our~~they ~~segments.~~exclude Wetransactions ~~define~~not ~~gross~~related ~~profit~~to asour ~~sales~~core ~~less~~cash ~~the~~operating ~~cost~~activities ~~of crude oil~~ and ~~other~~provide ~~feedstocks,~~metrics ~~LCM/LIFO~~to ~~adjustments,~~analyze ~~and~~the ~~other~~profitability ~~production-related~~of ~~expenses,~~ the ~~most~~core ~~significant~~cash ~~portion~~operations of ~~which~~our ~~includes labor, plant fuel, utilities, contract services, maintenance, transportation, RINs, depreciation and amortization and processing materials~~segments. We ~~use~~define segment Adjusted gross profit as ansegment ~~indicator~~gross ofprofit ~~our~~excluding ~~ability to manage margins in our business over~~ the ~~long-term.~~impact ~~The~~of ~~increase~~(a) LCM orinventory ~~decrease~~adjustments; ~~in selling prices typically lags behind~~ (b) the ~~rising~~impact orof ~~falling~~liquidation ~~costs, respectively,~~ of ~~feedstocks~~inventory ~~throughout~~layers ~~our~~calculated ~~business.~~using ~~Other~~the ~~than~~LIFO ~~plant~~method; ~~fuel,~~ (c) RINs mark-to-market adjustments,; (d) depreciation and ~~LCM/LIFO~~amortization; ~~adjustments,~~and ~~production~~(e) all ~~related~~extraordinary, ~~expenses~~unusual ~~generally~~or ~~remain~~non-recurring ~~stable~~items ~~across~~of ~~broad~~revenue ~~ranges~~or ~~but~~cost ~~can~~of ~~fluctuate depending on maintenance activities performed during a specific period~~sales.

Segment Adjusted gross profit. Specialty Products and Solutions, Montana/Renewables and Performance Brands products segment Adjusted gross profit measures are useful as they exclude transactions not related to our core cash operating activities and provide metrics to analyze the profitability of the core cash operations of our segments. We define segment Adjusted gross profit as segment gross profit excluding the impact of (a) LCM inventory adjustments; (b) the impact of liquidation of inventory layers calculated using the LIFO method; (c) RINs mark-to-market adjustments; (d) depreciation and amortization; and (e) all extraordinary, unusual or non-recurring items of revenue or cost of sales. During the first quarter of 2023, the CODM changed the definition and calculation of Adjusted gross profit, which we use for evaluating performance, allocating resources and managing the business. The revised definition and calculation of Adjusted gross profit now excludes the impact of all extraordinary, unusual or non-recurring items of revenue or cost of sales (see clause (e) above). Historically, we have made adjustments for these items in our calculation of Adjusted EBITDA and we believe this revised definition of Adjusted gross profit better reflects the performance of our Company’s business segments. Adjusted gross profit has been revised for all periods presented to consistently reflect this change.

Segment Adjusted EBITDA. We believe that Specialty Products and Solutions, Montana/Renewables and Performance Brands segment Adjusted EBITDA measures are useful as they exclude transactions not related to our core cash operating activities and provide metrics to analyze our ability to pay interest to our noteholders. Adjusted EBITDA allows us to meaningfully analyze the trends and performance of our core cash operations as well as to make decisions regarding the allocation of resources to segments. Corporate Adjusted EBITDA primarily reflects general and administrative costs.

44Results of Operations for the Three Months Ended March 31, 2024 and 2023

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Results of Operations for the Three and Nine Months Ended September 30, 2023 and 2022

Production Volume. 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.

Three Months Ended March 31,

~~Three Months Ended September 30,~~

~~Nine Months Ended September 30,~~

2024

~~2023~~

2023

~~2022~~

% Change

~~% Change~~

~~2023~~

~~2022~~

~~% Change~~

(In bpd)

~~(In bpd)~~

Total sales volume (1)

83,602

~~82,787~~

76,856

~~75,789~~

8.8

~~9.2~~%

~~79,660~~

~~85,859~~

~~(7.2)~~

Total feedstock runs (2)

71,548

~~82,409~~

71,559

~~75,722~~

—

~~8.8~~%

~~76,157~~

~~84,133~~

~~(9.5)~~

Facility production: (3)

Specialty Products and Solutions:

Lubricating oils

11,187

~~9,258~~

10,297

~~11,681~~

8.6

~~(20.7)~~%

~~10,013~~

~~11,039~~

~~(9.3)~~

Solvents

7,179

~~7,165~~

8,321

~~7,134~~

(13.7)

~~0.4~~%

~~7,176~~

~~6,963~~

~~3.1~~

Waxes

1,407

~~1,417~~

1,375

~~1,611~~

2.3

~~(12.0)~~%

~~1,369~~

~~1,445~~

~~(5.3)~~

Fuels, asphalt and other by-products

31,915

~~42,240~~

34,473

~~43,716~~

(7.4)

~~(3.4)~~%

~~37,630~~

~~41,043~~

~~(8.3)~~

Total Specialty Products and Solutions

51,688

~~60,080~~

54,466

~~64,142~~

(5.1)

~~(6.3)~~%

~~56,188~~

~~60,490~~

~~(7.1)~~

Montana/Renewables:

Gasoline

3,547

~~3,615~~

4,406

~~1,675~~

(19.5)

~~115.8~~%

~~3,892~~

~~3,672~~

~~6.0~~

Diesel

2,703

~~3,140~~

2,651

~~3,396~~

2.0

~~(7.5)~~%

~~2,967~~

~~7,997~~

~~(62.9)~~

Jet fuel

355

~~526~~

509

~~714~~

(30.3)

~~(26.3)~~%

~~476~~

~~880~~

~~(45.9)~~

Asphalt, heavy fuel oils and other

4,147

~~4,461~~

4,229

~~3,630~~

(1.9)

~~22.9~~%

~~4,474~~

~~8,165~~

~~(45.2)~~

Renewable fuels

8,243

~~7,455~~

5,030

—

63.9

~~100.0~~%

~~6,607~~

—

~~100.0~~

Total Montana/Renewables

18,995

~~19,197~~

16,825

~~9,415~~

12.9

~~103.9~~%

~~18,416~~

~~20,714~~

~~(11.1)~~

Performance Brands

1,583

~~3,066~~

1,931

~~1,299~~

(18.0)

~~136.0~~%

~~2,588~~

~~1,510~~

~~71.4~~

Total facility production (3)

72,266

~~82,343~~

73,222

~~74,856~~

(1.3)

~~10.0~~%

~~77,192~~

~~82,714~~

~~(6.7)~~

(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.

4540

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The following table reflects our unaudited condensed consolidated results of operations and includes the non-GAAP financial measures EBITDA, Adjusted EBITDA and Distributable Cash Flow. For a reconciliation of EBITDA, Adjusted EBITDA and Distributable Cash Flow to Net income (loss) ~~attributable to partners~~, our most directly comparable financial performance measure calculated and presented in accordance with GAAP, please read “— Non-GAAP Financial Measures.”


	Three Months Ended March 31,	~~Three Months Ended September 30,~~					~~Nine Months Ended September 30,~~
		~~2023~~2024			~~2022~~2023		~~2023~~		~~2022~~
	(In millions)	~~(In millions)~~
Sales		$	1,149.4		$	1,165.0	$	3,204.1	$	3,686.9
				(As Restated)
Cost of sales			887.8			1,025.7		2,774.4		3,371.0
Sales	$	1,005.8		$	1,037.3
Gross profit			261.6			139.3		429.7		315.9
Cost of sales		927.3			940.7
Operating costs and expenses:
Gross profit		78.5			96.6
Selling			12.4			11.6		41.4		40.4
Operating costs and expenses:
General and administrative			40.2			43.3		104.5		98.4
Selling		13.7			13.5
Other operating (income) expense			(4.1)			2.5		4.1		16.8
General and administrative		23.3			37.1
Operating income			213.1			81.9		279.7		160.3
Other operating expense		5.2			3.0
Other income (expense):
Operating income		36.3			43.0
Interest expense			(58.7)			(41.8)		(163.7)		(136.0)
Other income (expense):
Debt extinguishment costs			(0.3)			(40.4)		(5.5)		(41.4)
Interest expense		(60.8)			(49.2)
Gain (loss) on derivative instruments		(16.9)	~~(54.3)~~		25.5	~~16.5~~		~~(14.5)~~		~~(73.2)~~
Other income (expense):			0.6			(0.1)		0.1		(3.1)
Other expense		—			(0.2)
Total other expense		(77.7)	~~(112.7)~~		(23.9)	~~(65.8)~~		~~(183.6)~~		~~(253.7)~~
Net income (loss) before income taxes		(41.4)	~~100.4~~		19.1	~~16.1~~		~~96.1~~		~~(93.4)~~
Income tax expense		0.2	~~0.5~~		0.5	~~1.5~~		~~1.4~~		~~2.8~~
Net income (loss)	$	$(41.6)	~~99.9~~	$	$18.6	~~14.6~~	$	~~94.7~~	$	~~(96.2)~~
Net loss attributable to noncontrolling interest			(3.1)			(1.1)		(18.5)		(1.1)
EBITDA	$	55.4		$	97.8
Net income (loss) attributable to partners		$	103.0		$	15.7	$	113.2	$	(95.1)
Adjusted EBITDA	$	21.6		$	77.3
EBITDA		$	191.6		$	83.4	$	362.6	$	117.1
Distributable Cash Flow	$	(59.6)		$	4.8
Adjusted EBITDA		$	75.5		$	127.0	$	220.9	$	326.1
Distributable Cash Flow		$	(19.9)		$	43.8	$	(22.5)	$	118.2

Non-GAAP Financial Measures

We include in this Quarterly Report the non-GAAP financial measures EBITDA, Adjusted EBITDA and Distributable Cash Flow. We provide reconciliations of EBITDA, Adjusted EBITDA and Distributable Cash Flow to Net income (loss) ~~attributable to partners~~, our most directly comparable financial performance measure calculated and presented in accordance with GAAP.

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

●

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

●

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

●

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

●

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

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

We define EBITDA for any period as net income (loss) attributable to partners plus interest expense (including amortization of debt issuance costs), income taxes and depreciation and amortization. Historically, we considered net income (loss) to be the most directly comparable GAAP measure to EBITDA. Commencing with the third quarter of 2022, we reported net loss attributable to noncontrolling interest related to the preferred equity investment from Warburg Pincus in the Montana Renewables business. As a result of this change, we believe net income (loss) attributable to partners is the most directly comparable GAAP measure to EBITDA.41

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

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

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

We define Distributable Cash Flow for any period as Adjusted EBITDA less replacement and environmental capital expenditures, turnaround costs, cash interest expense (consolidated interest expense less non-cash interest expense), gain (loss) from unconsolidated affiliates, net of cash distributions and income tax expense (benefit).

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

The definition of Adjusted EBITDA presented in this Quarterly Report is similar to the calculation of “Consolidated Cash Flow” contained in the indentures governing our Senior Notes (as defined in this Quarterly Report) and the calculation of “Consolidated EBITDA” contained in the Credit Agreement. We are required to report Consolidated Cash Flow to the holders of our Senior Notes and Consolidated EBITDA to the lenders under our revolving credit facility, and these measures are used by them to determine our compliance with certain covenants governing those debt instruments. Please read Note 8 -— “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report for additional details regarding the covenants governing our debt instruments.

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

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The following tables present a reconciliation of Net income (loss) ~~attributable to partners~~, our most directly comparable GAAP financial performance measure to EBITDA, Adjusted EBITDA and Distributable Cash Flow, for each of the periods indicated.


	Three Months Ended March 31,	~~Three Months Ended September 30,~~					~~Nine Months Ended September 30,~~
	2024	~~2023~~		2023	~~2022~~		~~2023~~		~~2022~~
	(In millions)	~~(In millions)~~
Reconciliation of Net income (loss) attributable to partners to EBITDA, Adjusted EBITDA and Distributable Cash Flow:
Reconciliation of Net income (loss) to EBITDA, Adjusted EBITDA and Distributable Cash Flow:					(As Restated)
Net income (loss) attributable to partners		$	103.0		$	15.7	$	113.2	$	(95.1)
Net income (loss)	$	(41.6)		$	18.6
Add:
Interest expense		60.8	~~58.7~~		49.2	~~41.8~~		~~163.7~~		~~136.0~~
Depreciation and amortization		36.0	~~34.0~~		29.5	~~25.3~~		~~96.7~~		~~74.3~~
Income tax expense		0.2	~~0.5~~		0.5	~~1.5~~		~~1.4~~		~~2.8~~
Noncontrolling interest adjustments			(4.6)			(0.9)		(12.4)		(0.9)
EBITDA	$	55.4		$	97.8
EBITDA		$	191.6		$	83.4	$	362.6	$	117.1
Add:
Add:
LCM / LIFO loss	$	9.0		$	19.7
LCM / LIFO (gain) loss		$	(4.5)		$	(0.5)	$	9.4	$	(7.7)
Unrealized gain on derivative instruments		(35.7)			(41.0)
Unrealized (gain) loss on derivative instruments			36.3			(28.1)		(18.8)		47.5
Debt extinguishment costs		0.2			—
Debt extinguishment costs			0.3			40.4		5.5		41.4
Amortization of turnaround costs		9.4			7.7
Amortization of turnaround costs			9.7			4.9		27.0		16.4
RINs mark-to-market gain		(71.1)			(46.1)
Gain on impairment and disposal of assets			—			(0.2)		—		(0.2)
Equity-based compensation and other items		(7.3)			9.0
RINs mark-to-market (gain) loss			(173.4)			14.3		(215.9)		92.4
Other non-recurring expenses (1)		60.8			29.5
Equity-based compensation and other items			13.8			13.0		22.5		16.6
Noncontrolling interest adjustments		0.9			0.7
Other non-recurring (income) expenses (1)			2.4			(0.2)		35.5		2.6
Adjusted EBITDA	$	21.6		$	77.3
Noncontrolling interest adjustments			(0.7)			—		(6.9)		—
Less:
Adjusted EBITDA		$	75.5		$	127.0	$	220.9	$	326.1
Replacement and environmental capital expenditures (2)	$	16.7		$	17.2
Less:
Cash interest expense (3)		58.8			47.7
Replacement and environmental capital expenditures (2)		$	21.9		$	26.5	$	53.6	$	53.3
Turnaround costs		5.5			7.1
Cash interest expense (3)			57.2			40.5		159.5		119.6
Income tax expense		0.2			0.5
Turnaround costs			15.8			14.7		28.9		32.2
Distributable Cash Flow	$	(59.6)		$	4.8
Income tax expense			0.5			1.5		1.4		2.8
Distributable Cash Flow		$	(19.9)		$	43.8	$	(22.5)	$	118.2

(1) For the ~~nine~~three months ended ~~September~~March 3031, 2024, other non-recurring expenses included a $51.9 million realized loss on derivatives related to the embedded derivatives for our inventory financing arrangements. For the three months ended March 31, 2023, other non-recurring expenses included a $28.4 million charge to cost of sales for losses under firm purchase commitments.

(2)	Replacement capital expenditures are defined as those capital expenditures which do not increase operating capacity or reduce operating costs and exclude turnaround costs. Environmental capital expenditures include asset additions to meet or exceed environmental and operating regulations.

(3)	Represents consolidated interest expense less non-cash interest expense.

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Changes in Results of Operations for the Three Months Ended ~~September~~March 3031, ~~2023~~2024 and ~~2022~~2023

Sales. Sales decreased $1531.65 million, or 1.3.0%, to $1,~~149~~005.48 million in the three months ended ~~September~~March 3031, ~~2023~~2024, from $1,~~165~~037.03 million in the same period in ~~2022~~2023. Sales for each of our principal product categories in these periods were as follows:


	Three Months Ended ~~September~~March 3031,
	~~2023~~2024		~~2022~~2023		% Change
	(InDollars in millions, except barrel and per barrel data)
Sales by segment:
Specialty Products and Solutions:
Lubricating oils	$	~~175~~189.87	$	~~250~~215.42	(2911.8)	%
Solvents		92102.14		~~119~~106.26	(223.79)	%
Waxes		4039.10		5044.02	(1911.8)	%
Fuels, asphalt and other by-products (1)		~~437~~350.75		~~515~~372.07	(156.0)	%
Total Specialty Products and Solutions	$	~~745~~681.76	$	~~934~~738.67	(207.27)	%
Total Specialty Products and Solutions sales volume (in barrels)		5,~~524~~410,000		5,~~699~~179,000	(34.1)5	%
Average Specialty Products and Solutions sales price per barrel	$	~~134~~125.99	$	~~163~~142.9963	(1711.7)	%
Montana/Renewables:
Gasoline	$	4731.96	$	3542.29	36(26.13)	%
Diesel		3927.9		6832.49	(4115.72)	%
Jet Fuel		54.96		104.19	(~~41.~~6.1)	%
Asphalt, heavy fuel oils and other (2)		5030.21		4020.35	2446.68	%
Renewable fuels		~~184~~150.63		—118.6	~~100~~26.07	%
Total Montana/Renewables	$	~~328~~244.5	$	~~154~~219.08	~~113~~11.32	%
Total Montana/Renewables sales volume (in barrels)		12,~~961~~055,000		1,~~151~~611,000	7027.46	%
Average Montana/Renewables sales price per barrel	$	~~167~~118.5298	$	~~133~~136.8044	25(12.28)	%
Performance Brands:
Total Performance Brands (3)	$	7579.27	$	7678.48	(1.6)1	%
Total Performance Brands sales volume (in barrels)		~~131~~144,000		~~122~~127,000	713.4	%
Average Performance Brands sales price per barrel	$	~~574~~553.0547	$	~~626~~620.2347	(810.38)	%

Total sales	$	1,~~149~~005.48	$	1,~~165~~037.03	(1.3.0)	%
Total sales volume (in barrels)		7,616,000		6,972,000	9.2	%
Total Specialty Products and Solutions, Montana/Renewables, and Performance Brands sales volume (in barrels)		7,609,000		6,917,000	10.0	%

(1)

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

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

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

The components of the $188.9 million decrease in Specialty Products and Solutions segment sales for the three months ended September 30, 2023, as compared to the three months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Volume	$	(28.7)
Sales price		(160.2)
Total Specialty Products and Solutions segment sales decrease	$	(188.9)

~~Specialty~~The ~~Products~~components ~~and~~of ~~Solutions~~the ~~segment~~$57.1 ~~sales~~million ~~decreased~~decrease ~~period~~in ~~over~~Specialty ~~period,~~Products ~~primarily~~and ~~due~~Solutions tosegment ~~lower~~sales ~~prices~~for asthe ~~market~~three ~~prices~~months ~~have~~ended ~~slowly~~March 31, 2024, ~~regressed~~as ~~from~~compared to the ~~record~~three ~~high~~months ~~price~~ended ~~environment~~March 31, 2023, ~~experienced~~were inas ~~the prior year comparative period.~~ follows:


	Dollar Change
	(In millions)
Volume	$	32.8
Sales price		(89.9)
Total Specialty Products and Solutions segment sales decrease	$	(57.1)

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The unfavorable volumes impact was the result of required maintenance completed at our Shreveport facility during the quarter, which resulted in a loss of approximately 300,000 barrels of lube oil and wax sales.

The components of the $174.5 million increase in Montana/Renewables segment sales for the three months ended September 30, 2023, as compared to the three months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Sales price	$	66.1
Volume		108.4
Total Montana/Renewables segment sales increase	$	174.5

Montana/Renewables segment sales increased due to higher production volumes as the legacy specialty asphalt facility operated at a higher utilization during the current year quarter in comparison to the prior year comparative period. The facility completed a turnaround during the same period of 2022, which reduced production rates and sales volumes. Additionally, the Montana Renewables facility was operating during the current year quarter, but was still under construction during the prior year comparative period. The favorable price impact was primarily the result of selling higher priced renewable fuels products in the current year period.44

The components of the $1.2 million decrease in Performance Brands segment sales for the three months ended September 30, 2023, as compared to the three months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Volume	$	5.1
Sales price		(6.3)
Total Performance Brands segment sales decrease	$	(1.2)

Performance Brands segment sales decreased due to lower prices as a result of product mix. The unfavorable price impact was partially offset by an increase in sales volumes.

Gross Profit. Gross profit increased $122.3 million, or 87.8%, to $261.6 million in the three months ended September 30, 2023, from $139.3 million in the same period in 2022. Gross profit for our business segments were as follows:


	Three Months Ended September 30,
	2023			2022			% Change
	(Dollars in millions, except per barrel data)
Gross profit by segment:
Specialty Products and Solutions:
Gross profit	$	158.9		$	123.4		28.8	%
Percentage of sales		21.3	%		13.2	%	8.1	%
Specialty Products and Solutions gross profit per barrel	$	28.77		$	21.65		32.9	%
Montana/Renewables:
Gross profit (loss)	$	81.7		$	(1.1)		(7,527.3)	%
Percentage of sales		24.9	%		(0.7)	%	25.6	%
Montana/Renewables gross profit (loss) per barrel	$	41.66		$	(0.96)		(4,439.8)	%
Performance Brands:
Gross profit	$	21.0		$	17.0		23.5	%
Percentage of sales		27.9	%		22.3	%	5.6	%
Performance Brands gross profit per barrel	$	160.31		$	139.34		15.0	%

Total gross profit	$	261.6		$	139.3		87.8	%
Percentage of sales		22.8	%		12.0	%	10.8	%

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Specialty Products and Solutions segment sales decreased period over period, primarily due to a lower commodity price environment in the current year period. This impact was partially offset by an increase in sales volumes as a result of strong market demand.

The components of the $24.7 million increase in Montana/Renewables segment sales for the three months ended March 31, 2024, as compared to the three months ended March 31, 2023, were as follows:


	Dollar Change
	(In millions)
Sales price	$	(35.8)
Volume		60.5
Total Montana/Renewables segment sales increase	$	24.7

Montana/Renewables segment sales increased primarily due to stabilized production volumes at our Montana Renewables facility during the quarter in comparison to lower volumes in the prior year comparative period as a result of the start-up of the facility. This impact was partially offset by the weaker price environment in the current year period.

The components of the $350.59 million increase in ~~Specialty~~Performance ~~Products~~Brands ~~and Solutions~~ segment ~~gross~~sales ~~profit~~ for the three months ended ~~September~~March 3031, ~~2023~~2024, as compared to the three months ended ~~September~~March 3031, ~~2022~~2023, were as follows:


	Dollar Change
	(In millions)
Three months ended September 30, 2022 reported gross profit	$	123.4
Cost of materials		64.7
LCM / LIFO inventory adjustments		6.4
Volumes		(7.8)
Operating costs		8.4
RINs expense		123.9
Sales price		(160.1)
Three months ended September 30, 2023 reported gross profit	$	158.9

The increase in Specialty Products and Solutions segment gross profit for the three months ended September 30, 2023 as compared to the same period in 2022, was primarily due to the significant decline in RINs prices in the current quarter, which favorably benefited our business. This impact was partially off-set by lower specialties and fuels unit margins primarily as a result of the weaker margin environment experienced during the current year period and the unplanned downtime that occurred at our Shreveport facility, which limited production and sales of our higher priced specialties products, including lubricants and waxes. The unfavorable impact of lower volumes was also the result of required maintenance performed at our Shreveport facility during the current year period.


	Dollar Change
	(In millions)
Sales price	$	(9.6)
Volume		10.5
Total Performance Brands segment sales increase	$	0.9

The components of the $82.8 million increase in Montana/Renewables segment gross profit for the three months ended September 30, 2023, as compared to the three months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Three months ended September 30, 2022 reported gross profit (loss)	$	(1.1)
Cost of materials		(46.3)
LCM / LIFO inventory adjustments		(2.0)
Volumes		33.4
RINs expense		61.2
Operating costs		(29.6)
Sales price		66.1
Three months ended September 30, 2023 reported gross profit	$	81.7

~~The~~Performance ~~increase~~Brands ~~in Montana/Renewables~~ segment sales ~~gross profit for the three months ended September~~increased ~~30, 2023,~~primarily ~~as compared to the same period in 2022, was~~ due to ~~our~~increases ~~Montana Renewables facility operating during the current year period, resulting~~ in ~~the production and~~ sales ofvolumes ~~higher priced renewable fuels products. Additionally, margins improved~~ as a result of ~~the~~strong ~~significant~~market ~~decline in RINs prices in the current quarter~~demand. The unfavorable cost of materials impact was due to the procurement of more expensive renewable feedstocks that are processed at the Montana Renewables facility. Current quarter results were unfavorably impacted by higher operating costs, which were associated with the start-up of the Montana Renewables facility.

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The components of the $4.0 million increase in Performance Brands segment gross profit for the three months ended September 30, 2023, as compared to the three months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Three months ended September 30, 2022 reported gross profit	$	17.0
Sales price		(6.3)
Operating costs		2.6
LCM / LIFO inventory adjustments		(0.3)
Volume		1.7
Cost of materials		6.3
Three months ended September 30, 2023 reported gross profit	$	21.0

~~The~~Gross ~~increase~~Profit. Gross inprofit decreased ~~Performance~~$18.1 ~~Brands~~million, ~~segment~~or ~~gross~~18.7%, ~~profit~~to $78.5 ~~for~~ million in the three months ended ~~September~~March 3031, ~~2023~~2024, asfrom ~~compared~~$96.6 tomillion in the same period in ~~2022,~~2023. ~~was~~Gross ~~primarily~~profit ~~driven~~for byour ~~$3.2 million of~~ business ~~interruption~~segments ~~insurance~~were ~~proceeds~~as ~~received in the current year period.~~ follows:

Interest expense. Interest expense increased $16.9 million, or 40.4%, to $58.7 million in the three months ended September 30, 2023, from $41.8 million in the same period in 2022. The increase was primarily due to interest expense incurred for our 2028 Notes and the MRL Term Loan Credit Agreement in the current quarter, which was absent the prior year comparative period. The increase in interest expense in the current year period was partially offset by the absence of interest expense incurred in the prior year comparative period for outstanding borrowings under the MRL credit facility, which were repaid in August 2022.

Debt extinguishment costs. There was $0.3 million of debt extinguishment costs in the three months ended September 30, 2023, in comparison to $40.4 million of debt extinguishment costs in the three months ended September 30, 2022. Debt extinguishment costs in the prior year period comprised of $2.1 million in conjunction with the repurchase of $36.5 million aggregate principal amount of the 2025 Notes and $38.3 million in conjunction with the repayment of all borrowings under the MRL credit facility.

Gain (loss) on derivative instruments. There was a $54.3 million loss on derivative instruments in the three months ended September 30, 2023, compared to a $16.5 million gain in the same period in 2022. The $18.0 million realized loss on derivative instruments in the current year period was due to the settlement of our crack spread swaps positions during the period, as compared to a $11.6 million realized loss in the comparative period for the settlement of crack spread swaps positions. The unrealized loss on derivative instruments was primarily the result of a $24.6 million unrealized loss on the inventory financing embedded derivative, coupled with a $11.7 million unrealized loss for our crack spread swaps positions. The Company recorded a combined $28.1 million unrealized gain for the inventory financing embedded derivative and crack spread swaps positions in the comparative period.

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Changes in Results of Operations for the Nine Months Ended September 30, 2023 and 2022

Sales. Sales decreased $482.8 million, or 13.1%, to $3,204.1 million in the nine months ended September 30, 2023, from $3,686.9 million in the same period in 2022. Sales for each of our principal product categories in these periods were as follows:


	Nine Months Ended September 30,
	2023		2022		% Change
	(Dollars in millions, except barrel and per barrel data)
Sales by segment:
Specialty Products and Solutions:
Lubricating oils	$	577.2	$	705.2	(18.2)	%
Solvents		294.9		331.8	(11.1)	%
Waxes		124.5		144.3	(13.7)	%
Fuels, asphalt and other by-products (1)		1,171.9		1,501.9	(22.0)	%
Total Specialty Products and Solutions	$	2,168.5	$	2,683.2	(19.2)	%
Total Specialty Products and Solutions sales volume (in barrels)		15,999,000		16,822,000	(4.9)	%
Average Specialty Products and Solutions sales price per barrel	$	135.54	$	159.51	(15.0)	%
Montana/Renewables:
Gasoline	$	131.6	$	161.6	(18.6)	%
Diesel		108.7		365.7	(70.3)	%
Jet Fuel		16.5		36.3	(54.5)	%
Asphalt, heavy fuel oils and other (2)		107.9		210.4	(48.7)	%
Renewable fuels		431.4		—	100.0	%
Total Montana/Renewables	$	796.1	$	774.0	2.9	%
Total Montana/Renewables sales volume (in barrels)		5,353,000		6,220,000	(13.9)	%
Average Montana/Renewables sales price per barrel	$	148.72	$	124.44	19.5	%
Performance Brands:
Total Performance Brands (3)	$	239.5	$	229.7	4.3	%
Total Performance Brands sales volume (in barrels)		395,000		397,000	(0.5)	%
Average Performance Brands sales price per barrel	$	606.33	$	578.59	4.8	%

Total sales	$	3,204.1	$	3,686.9	(13.1)	%
Total Specialty Products and Solutions, Montana/Renewables, and Performance Brands sales volume (in barrels)		21,747,000		23,439,000	(7.2)	%

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


	Three Months Ended March 31,
	2024			2023			% Change

	(Dollars in millions, except per barrel data)
Gross profit by segment:
Specialty Products and Solutions:
Gross profit	$	85.3		$	109.9		(22.4)	%
Percentage of sales		12.5	%		14.9	%	(2.4)	%
Specialty Products and Solutions gross profit per barrel	$	15.77		$	21.22		(25.7)	%
Montana/Renewables:
Gross profit (loss)	$	(29.1)		$	(36.9)		(21.1)	%
Percentage of sales		(11.9)	%		(16.8)	%	4.9	%
Montana/Renewables gross profit (loss) per barrel	$	(14.16)		$	(22.91)		(38.2)	%
Performance Brands:
Gross profit	$	22.3		$	23.6		(5.5)	%
Percentage of sales		28.0	%		29.9	%	(1.9)	%
Performance Brands gross profit per barrel	$	154.86		$	185.83		(16.7)	%

Total gross profit	$	78.5		$	96.6		(18.7)	%
Percentage of sales		7.8	%		9.3	%	(1.5)	%

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

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

The components of the $514.7 million decrease in Specialty Products and Solutions segment sales for the nine months ended September 30, 2023, as compared to the nine months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Volume	$	(131.3)
Sales price		(383.4)
Total Specialty Products and Solutions segment sales decrease	$	(514.7)

53The components of the $24.6 million decrease in Specialty Products and Solutions segment gross profit for the three months ended March 31, 2024, as compared to the three months ended March 31, 2023, were as follows:

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Specialty Products and Solutions segment sales decreased period over period, primarily due to the weaker price environment in the current year period and lower throughput. The unfavorable volumes impact was due to planned turnarounds at our Shreveport, Cotton Valley, and Princeton facilities in the current year period and unplanned outages as a result of the severe weather experienced in Northwest Louisiana during the current year.

The components of the $22.1 million increase in Montana/Renewables segment sales for the nine months ended September 30, 2023, as compared to the nine months ended September 30, 2022, were as follows:


	Dollar Change
	(In millions)
Sales price	$	130.1
Volume		(108.0)
Total Montana/Renewables segment sales increase	$	22.1

Montana/Renewables segment sales increased primarily due to higher sales prices resulting from sales of higher priced renewable fuels in the current year period. Lower volumes were the result of the start-up of the Montana Renewables facility and the impact of modifying our legacy Great Falls asphalt plant to operate at a new and lower nameplate capacity. Lower production volumes during the initial start-up of our Montana Renewables facility were in-line with our sequential commissioning plans for the facility.


	Dollar Change
	(In millions)
Three months ended March 31, 2023 reported gross profit	$	109.9
Cost of materials		27.6
Operating costs		(2.0)
LCM / LIFO inventory adjustments		4.8
Volumes		8.5
Sales price		(89.9)
RINs expense		26.4
Three months ended March 31, 2024 reported gross profit	$	85.3

The ~~components~~decrease in ofSpecialty ~~the~~Products ~~$9.8~~and ~~million~~Solutions ~~increase in Performance Brands~~ segment ~~sales~~gross profit for the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024, as compared to the ~~nine~~same ~~months~~period ~~ended~~in ~~September 30~~2023, ~~2022,~~ ~~were~~was asprimarily ~~follows:~~due to the regression of the record high specialties and fuels margins environment in the prior year period. The favorable volumes impact was the result of strong market demand.


	Dollar Change
	(In millions)
Sales price	$	10.9
Volume		(1.1)
Total Performance Brands segment sales increase	$	9.8

The components of the $7.8 million increase in Montana/Renewables segment gross profit (loss) for the three months ended March 31, 2024, as compared to the three months ended March 31, 2023, were as follows:

Performance Brands segment sales increased primarily due to increases in product prices.


	Dollar Change
	(In millions)
Three months ended March 31, 2023 reported gross profit (loss)	$	(36.9)
Cost of materials		55.4
LCM / LIFO inventory adjustments		4.6
Volumes		1.0
RINs expense		9.2
Operating costs		(26.6)
Sales price		(35.8)
Three months ended March 31, 2024 reported gross profit (loss)	$	(29.1)

54The increase in Montana/Renewables segment gross profit for the three months ended March 31, 2024, as compared to the same period in 2023, was primarily due to higher margins associated with the sales of renewable fuel products at our Montana Renewables facility in the current year period. The unfavorable impact from higher operating costs was primarily due to higher utility costs.

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Gross Profit. Gross profit increased $113.8 million, or 36.0%, to $429.7 million in the nine months ended September 30, 2023, from $315.9 million in the same period in 2022. Gross profit for our business segments were as follows:


	Nine Months Ended September 30,
	2023			2022			% Change
	(Dollars in millions, except per barrel data)
Gross profit by segment:
Specialty Products and Solutions:
Gross profit	$	314.5		$	229.2		37.2	%
Percentage of sales		14.5	%		8.5	%	6.0	%
Specialty Products and Solutions gross profit per barrel	$	19.66		$	13.63		44.2	%
Montana/Renewables:
Gross profit	$	49.2		$	42.2		16.6	%
Percentage of sales		6.2	%		5.5	%	0.7	%
Montana/Renewables gross profit per barrel	$	9.19		$	6.78		35.6	%
Performance Brands:
Gross profit	$	66.0		$	44.5		48.3	%
Percentage of sales		27.6	%		19.4	%	8.2	%
Performance Brands gross profit per barrel	$	167.09		$	112.09		49.1	%

Total gross profit	$	429.7		$	315.9		36.0	%
Percentage of sales		13.4	%		8.6	%	4.8	%

The components of the $1.3 million decrease in Performance Brands segment gross profit for the three months ended March 31, 2024, as compared to the three months ended March 31, 2023, were as follows:


	Dollar Change
	(In millions)
Three months ended March 31, 2023 reported gross profit	$	23.6
Sales price		(9.6)
Operating costs		(4.8)
LCM / LIFO inventory adjustments		1.3
Volume		3.6
Cost of materials		8.2
Three months ended March 31, 2024 reported gross profit	$	22.3

The ~~components of~~ ~~the~~decrease ~~$85.3 million increase~~ in ~~Specialty~~Performance ~~Products~~Brands ~~and Solutions~~ segment gross profit for the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024, as compared to the ~~nine~~same ~~months~~period ~~ended~~in ~~September 30~~2023, ~~2022~~ was primarily due to the partial receipt of proceeds from the Company’s business interruption insurance policy included in the prior year period results. This segment continues to benefit from strong unit margins, ~~were~~reflective asof ~~follows:~~stabilized input costs in our branded and consumer markets and an increase in industrial volumes.


	Dollar Change
	(In millions)
Nine months ended September 30, 2022 reported gross profit	$	229.2
Cost of materials		321.2
Operating costs		(18.3)
LCM / LIFO inventory adjustments		0.3
Volumes		(29.3)
Sales price		(383.4)
RINs expense		194.8
Nine months ended September 30, 2023 reported gross profit	$	314.5

The increase in Specialty Products and Solutions segment gross profit for the nine months ended September 30, 2023, as compared to the same period in 2022, was primarily due to the significant decline in RINs prices in the current year. This impact was partially off-set by lower specialties and fuels unit margins as a result of the weaker margin environment experienced during the current year period. Also, current year results were unfavorably impacted by higher operating expenses and lower volumes as a result of planned turnarounds completed at our Shreveport, Cotton Valley, and Princeton facilities and unplanned outages as a result of the severe weather experienced in Northwest Louisiana during the current year period.

The components of the $7.0 million increase in Montana/Renewables segment gross profit for the nine months ended September 30, 2023, as compared to the nine months ended September 30, 2022, were as follows:

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	Dollar Change
	(In millions)
Nine months ended September 30, 2022 reported gross profit	$	42.2
Cost of materials		(88.4)
Loss on firm purchase commitments		(28.4)
LCM / LIFO inventory adjustments		(14.8)
Volumes		(27.7)
RINs expense		107.6
Operating costs		(71.4)
Sales price		130.1
Nine months ended September 30, 2023 reported gross profit	$	49.2

General and administrative. General and administrative expenses decreased $13.8 million, or 37.2%, to $23.3 million in the three months ended March 31, 2024, from $37.1 million in the same period in 2023. The decrease was primarily due to a $16.4 million decrease in equity-based compensation related expenses, partially offset by a $0.5 million increase in professional services fees. The decrease in equity-based compensation related expenses was primarily the result of changes in the Company’s unit price in the current year period in comparison to the prior year comparative period. The increase in professional services fees were primarily related to IT infrastructure support services.

~~The~~Interest expense. ~~increase~~Interest inexpense ~~Montana/Renewables~~increased ~~segment~~$11.6 ~~gross~~million, ~~profit~~or ~~for~~23.6%, to $60.8 million in the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024, asfrom ~~compared~~$49.2 tomillion in the same period in ~~2022,~~2023. The increase was primarily due to ~~the~~interest ~~significant~~expense ~~decline~~incurred infor ~~RINs~~our ~~prices~~2028 inNotes ~~the~~and ~~current year. This impact was coupled with~~ the ~~favorable~~MRL ~~impact~~Term ofLoan ~~higher~~Credit ~~margins~~Agreement ~~associated with sales of renewable fuels products at our Montana Renewables facility~~ in the current year period., ~~The~~which unfavorable impact for lower production volumes and higher operating costs were associated with the start-up of the Montana Renewables facility and the modification of our legacy Great Falls specialty asphalt facility. This impact was ~~coupled~~absent ~~with~~ the ~~unfavorable~~prior ~~impact of a charge for losses under firm purchase commitments recorded in the current~~ year comparative period.

~~The~~Gain ~~components~~(loss) ofon derivative instruments. ~~the~~There was a $2116.59 million ~~increase in Performance~~loss ~~Brands~~on ~~segment~~derivative ~~gross~~instruments ~~profit~~in ~~for~~ the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024, as compared to a $25.5 million gain in the ~~nine~~same ~~months~~period ~~ended~~in ~~September 30~~2023. The $52.6 million realized loss on derivative instruments in the current year period was primarily due to the realized loss on the embedded derivative recognized at the termination of the Shreveport inventory financing arrangement with Macquarie in the current period. The unrealized gain on derivative instruments was primarily related to the unrealized gain on the inventory financing embedded derivative of $41.7 million in the current year period, ~~2022,~~ ~~were~~compared asto ~~follows:~~an unrealized gain of $2.2 million in the prior year comparative period.


	Dollar Change
	(In millions)
Nine months ended September 30, 2022 reported gross profit	$	44.5
Sales price		10.9
Operating costs		7.4
LCM / LIFO inventory adjustments		(2.6)
Volume		(0.3)
Cost of materials		6.1
Nine months ended September 30, 2023 reported gross profit	$	66.0

The increase in Performance Brands segment gross profit for the nine months ended September 30, 2023, as compared to the same period in 2022, was primarily driven by higher unit margins as a result of input costs stabilizing in our branded and consumer markets. The favorable impact for operating costs was the result of partial receipt of proceeds from the Company’s business interruption insurance policy recorded in the current year period.

General and administrative. General and administrative expenses increased $6.1 million, or 6.2%, to $104.5 million in the nine months ended September 30, 2023, from $98.4 million in the same period in 2022. The increase was primarily due to a $5.8 million increase in equity-based compensation related expenses and a $13.9 million increase in professional services fees. The increase in equity-based compensation related expenses were primarily the result of an increase in the Company’s unit price in the current year period in comparison to the prior year comparative period. The increase in professional services fees were primarily related to IT infrastructure support services.

Interest expense. Interest expense increased $27.7 million, or 20.4%, to $163.7 million in the nine months ended September 30, 2023, from $136.0 million in the same period in 2022. The increase was primarily due to interest expense incurred for our 2028 Notes and the MRL Term Loan Credit Agreement in the current year period, which was absent the prior year comparative period. The increase in interest expense in the current year period was partially offset by the absence of interest expense incurred in the prior year comparative period for outstanding borrowings under the MRL credit facility, which were repaid in August 2022.

Gain (loss) on derivative instruments. There was a $14.5 million loss on derivative instruments in the nine months ended September 30, 2023, compared to a $73.2 million loss in the same period in 2022. The $33.3 million realized loss

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on derivative instruments in the current year period was due to the settlement of our crack spread swaps positions during the period. The unrealized gain on derivative instruments was primarily the result of a $39.7 million unrealized gain on crack spread swaps positions, partially off-set by the unrealized loss on the inventory financing embedded derivative of $20.9 million in the current year period, compared to an unrealized loss of $26.3 million in the prior year comparative period.

Liquidity and Capital Resources

General

The following should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources” included under Part II, Item 7 in our ~~2022~~2023 Annual Report. There have been no material changes in that information other than as discussed below. Also, see Note 7 — “Inventory Financing Agreements” and Note 8 — “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report for additional discussions related to our Supply and Offtake Agreements and our long-term debt.

Cash Flows from Operating, Investing and Financing Activities

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

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The following table summarizes our primary sources and uses of cash in each of the periods presented:


	~~Nine~~Three Months Ended ~~September~~March 3031,
	~~2023~~2024		~~2022~~2023
	(In millions)
Net cash provided by (used) in operating activities	$	(7.4)	$	150.7
Net cash used in operating activities	$	(94.0)	$	(26.7)
Net cash used in investing activities		(~~240~~20.30)		(~~376~~130.14)
Net cash provided by financing activities		~~232~~130.97		~~154~~133.01
Net decrease in cash, cash equivalents and restricted cash	$	(14.8)	$	(71.4)
Net increase (decrease) in cash, cash equivalents and restricted cash	$	16.7	$	(24.0)

Operating Activities. Operating activities used cash of $794.40 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024 compared to ~~providing~~using cash of $~~150~~26.7 million during the same period in ~~2022~~2023. The change was primarily driven by a decrease in net unit margins as a result of the weaker margin environment experienced during the current year period.

Investing Activities. Investing activities used cash of $~~240~~20.30 million during the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024 compared to a use of cash of $~~376~~130.14 million during the same period in ~~2022~~2023. The change is related to a decrease in cash expenditures for additions to property, plant and equipment in the current year period in comparison to the prior year. The cash expenditures for additions to property, plant and equipment in ~~both~~the ~~periods~~prior year period were mainly related to our Montana Renewables project.

57Financing Activities. Financing activities provided cash of $130.7 million in the three months ended March 31, 2024 compared to providing cash of $133.1 million during the same period in 2023. The change is primarily due to higher borrowings under our revolving credit facilities to support working capital and financing requirements, offset by an increase in net payments for our inventory financing arrangements.

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Financing Activities. Financing activities provided cash of $232.9 million in the nine months ended September 30, 2023 compared to providing cash of $154.0 million during the same period in 2022. The change is primarily due to the borrowings we received from the issuance of the 2028 Notes and the MRL Term Loan Credit Agreement, partially offset by repayments of our 2024 Secured Notes and 2025 Notes.

Capital Expenditures

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

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


	~~Nine~~Three Months Ended ~~September~~March 3031,
	~~2023~~2024		~~2022~~2023
	(In millions)
Capital improvement expenditures	$	~~186~~3.73	$	~~323~~113.02
Replacement capital expenditures		4415.68		4713.97
Environmental capital expenditures		9.0.9		53.45
Turnaround capital expenditures		285.95		327.21
Total	$	~~269~~25.25	$	~~408~~137.5

~~2023~~2024 Capital Spending Forecast

~~Excluding~~We ~~MRL capital expenditures, we~~ are forecasting total capital expenditures of approximately $~~125.0~~110 million to $~~145.0~~140 million in ~~2023~~2024. InOur ~~the~~forecasted ~~first nine months of 2023, we commissioned a renewable hydrogen plant, feedstock pre-treatment unit and SAF unit at our Montana Renewables facility. We financed $150.0 million of the~~ capital expenditures ~~for~~are ~~these~~primarily ~~projects~~related ~~through~~to ~~our~~growth ~~Master~~and ~~Lease~~sustainability ~~Agreement with Stonebriar~~projects. We anticipate that capital expenditure requirements will be provided primarily through cash flow from operations, cash on hand, available borrowings under our revolving credit facilities and by accessing capital markets as necessary. Further, we continue to anticipate that capital improvement expenditure requirements will be funded from borrowings under our revolving credit facilities or by funding accessed through capital markets. If future capital expenditures require expenditures in excess of our then-current cash flow from operations and borrowing availability under our credit facilities, we may be required to issue debt or equity securities in public or private offerings or incur additional borrowings under bank credit facilities to meet those costs.

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flow from operations and borrowing availability under our revolving credit facilities, we may be required to issue debt or equity securities in public or private offerings or incur additional borrowings under bank credit facilities to meet those costs.

Debt and Credit Facilities

As of ~~September~~March 3031, ~~2023~~2024, our primary debt and credit instruments consisted of the following:

● $~~500~~650.0 million senior secured revolving credit facility maturing in January 2027 (after giving effect to the Fourth Amendment to our revolving credit facility (the “Credit Facility Amendment”)), subject to borrowing base limitations, with a maximum letter of credit sub-limit equal to $255.0 million, which amount may be increased to 90% of revolver commitments in effect with the consent of the Agent (as defined in the Credit Agreement) (“revolving credit facility”);

●

$90.0 million senior secured revolving credit facility, with the option to request additional commitments of up to $15.0 million, maturing in November 2027 (the “MRL Revolving Credit Agreement”);

● $179.0 million of 9.25% Senior Secured First Lien Notes due 2024 (“2024 Secured Notes”);

●

$413.5 million of 11.00% Senior Notes due 2025 (“2025 Notes”);

●

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

● $325.0 million of 9.2575% Senior Notes due 2028 (“2028 Notes”);

● $74200.60 million of ~~borrowings~~9.25% ~~under~~Senior ~~our~~Secured ~~MRL~~First ~~Term~~Lien ~~Loan~~Notes ~~Credit~~due ~~Agreement;~~2029 ~~and~~(“2029 Secured Notes”);

58● $74.3 million of borrowings under our MRL Term Loan Credit Agreement; and

●

$380.6 million of financing through our MRL asset financing arrangements.

We were in compliance with all covenants under the debt instruments in place as of March 31, 2024 and believe we have adequate liquidity to conduct our business.

On January 17, 2024, the Company entered into the Fourth Amendment to its revolving credit facility (the “Credit Agreement”) governing its senior secured revolving credit facility maturing in January 2027, which provides maximum availability of credit under the revolving credit facility of $650.0 million, including a FILO tranche, subject to borrowing base limitations, and includes a $500.0 million incremental uncommitted expansion feature. Lenders under the revolving credit facility have a first priority lien on, among other things, the Company’s accounts receivable and inventory and substantially all of its cash (collectively, the “Credit Agreement Collateral”). Please refer to Note 8 — “Long-Term Debt” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

On March 7, 2024, the Company issued and sold $200.0 million in aggregate principal amount of 2029 Secured Notes in a private placement transaction in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended (the “Securities Act”). The 2029 Secured Notes were issued at par for net proceeds of $199.0 million, after deducting transaction expenses. The Company used the net proceeds from the private placement of the 2029 Secured Notes, together with cash on hand, to redeem all of its outstanding 9.25% Senior Secured First Lien Notes due 2024 (the “2024 Secured Notes”) and $50.0 million aggregate principal amount of its outstanding 11.00% Senior Notes due 2025 (the “2025 Notes”). Please refer to Note 8 — “Long-Term Debt” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

The borrowing base on our credit facilities increased from approximately $491.6 million as of March 31, 2023, to approximately $563.9 million at March 31, 2024. Our borrowing availability decreased from approximately $233.7 million at March 31, 2023, to approximately $187.9 million at March 31, 2024. Total liquidity, consisting of unrestricted cash and available funds under our credit facilities, decreased from $244.9 million at March 31, 2023 to $211.8 million at March 31, 2024.

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● $388.0 million of financing through our MRL asset financing arrangements.

We were in compliance with all covenants under the debt instruments in place as of September 30, 2023 and believe we have adequate liquidity to conduct our business.

On April 19, 2023, MRL and MRHL entered into the MRL Term Loan Credit Agreement, that provides for a $75.0 million term loan facility with a maturity date of April 19, 2028. Please refer to Note 8 — “Long-Term Debt” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information.

The borrowing base on our credit facilities decreased from approximately $500.0 million as of September 30, 2022, to approximately $453.7 million at September 30, 2023. Our borrowing availability decreased from approximately $374.8 million at September 30, 2022, to approximately $363.9 million at September 30, 2023. Total liquidity, consisting of unrestricted cash and available funds under our credit facilities, decreased from $391.2 million at September 30, 2022 to $377.6 million at September 30, 2023.

Inventory Financing

On ~~March 10~~January 17, ~~2023~~2024 (the “Effective Date”), ~~MRL~~the Company and ~~Macquarie~~J. Aron entered into ana ~~amendment~~Monetization toMaster Agreement (the ~~MRL~~“Master ~~Supply~~Agreement”), ~~and~~a ~~Offtake~~related Financing Agreement (the “~~SOA~~Financing Agreement”) toand ~~provide~~Supply ~~that~~and ~~agreement~~Offtake ~~will~~Agreement ~~expire~~(together onwith ~~September 30,~~the ~~2023.~~Master OnAgreement ~~September~~and ~~26,~~the ~~2023~~Financing Agreement, ~~MRL~~the ~~and~~“Shreveport ~~Macquarie~~Supply ~~entered~~and ~~into~~Offtake anAgreement”). ~~additional~~Pursuant ~~amendment~~ to the ~~MRL~~Shreveport ~~SOA,~~Supply ~~which~~and ~~extended~~Offtake ~~the~~Agreement, ~~termination~~J. ~~date~~Aron ~~from~~agreed ~~September 30~~to, ~~2023~~among toother ~~October 3~~things, ~~2023.~~purchase Infrom ~~connection~~the ~~with~~Company, ~~the~~or ~~expiration~~extend ofto the ~~MRL SOA~~Company, ~~MRL~~financial ~~and~~accommodations ~~Wells~~secured ~~Fargo~~by ~~entered~~crude ~~into~~oil ~~(i) an~~and ~~ISDA~~finished ~~2002~~products ~~Master~~located ~~Agreement~~at (the ~~“Master~~Company’s ~~Agreement”),~~Shreveport ~~(ii) a~~facility ~~Schedule~~on to the ~~ISDA~~Effective ~~2002~~Date ~~Master~~and ~~Agreement~~from ~~(the~~time ~~“Schedule”), (iii) a Credit Support Annex~~ to ~~the~~time, ~~Schedule~~up to ~~the~~maximum ~~ISDA~~volumes ~~2002~~specified ~~Master~~for ~~Agreement~~crude ~~(the~~oil ~~“Credit Support Annex”),~~ and ~~(iv) a~~categories ~~Renewable~~of ~~Fuel~~finished ~~and~~products, ~~Feedstock~~subject ~~Repurchase~~to ~~Master Confirmation (~~the ~~“Master~~Company’s ~~Confirmation”;~~repurchase ~~together~~obligations with ~~the~~respect ~~Master~~thereto. ~~Agreement,~~The ~~the~~Shreveport ~~Schedule~~Supply and ~~the~~Offtake ~~Credit~~Agreement ~~Support~~replaced ~~Annex,~~the ~~collectively,~~Company’s ~~the~~previous ~~“Facility~~inventory ~~Documents”).~~financing ~~Pursuant~~agreement towith ~~the~~Macquarie, ~~terms~~which ofterminated ~~the~~on ~~Facility~~January ~~Documents~~17, ~~Wells~~2024. ~~Fargo~~Please ~~will~~refer ~~provide~~to ~~MRL~~Note 7 — ~~total~~“Inventory ~~liquidity~~Financing ofAgreements” upin toPart I, ~~$120.0~~Item 1 ~~million.~~“Financial ~~The~~Statements — ~~financing~~Notes to ~~arrangements~~Unaudited ~~under~~Condensed ~~the~~Consolidated ~~Wells~~Financial ~~Facility~~Statements” ~~Documents~~for ~~replaced~~additional ~~the~~information ~~arrangements~~regarding ~~under~~our ~~the~~Supply ~~Macquarie~~and ~~SOA~~Offtake Agreements.

Please refer to Note 15 — “Subsequent Events” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information regarding the MRL financing arrangement with Wells Fargo.

On March 20, 2023, Macquarie provided notice of Macquarie’s election of its right to terminate the Shreveport SOA and the Montana SOA, in each case effective December 31, 2023. When the Shreveport SOA and the Montana SOA were entered into, the inventories associated with such agreements were taken out of the Company’s revolving credit facility borrowing base. The Company intends to amend its revolving credit facility to re-include the inventories, subject to approval by the lenders under the revolving credit facility.

Please refer to Note 7 — “Inventory Financing Agreements” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for additional information regarding our Supply and Offtake Agreements.

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Short-Term Liquidity

As of ~~September~~March 3031, ~~2023~~2024, our principal sources of short-term liquidity were (i) $~~363~~187.9 million of availability under our credit facilities, (ii) inventory financing agreements related to ~~the~~our ~~Great Falls facility,~~ Shreveport facility, and Montana Renewables facility and (iii) $1323.79 million of unrestricted cash on hand. Borrowings under our revolving credit facilities can be used for, among other things, working capital, capital expenditures and other lawful partnership purposes including acquisitions. For additional information regarding our revolving credit facilities, see Note 8 -— “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report.

Long-Term Financing

In addition to our principal sources of short-term liquidity listed above, subject to market conditions, we may meet our cash requirements (other than distributions of Available Cash (as defined in our partnership agreement) to our common unitholders) through the issuance of long-term notes or additional common units.

From time to time, we issue long-term debt securities referred to as our senior notes. All of our outstanding senior notes, ~~other than the 2024 Secured Notes,~~ are unsecured obligations that rank equally with all of our other senior debt obligations to the extent they are unsecured. As of ~~September~~March 3031, ~~2023~~2024, we had $~~179.0 million in 2024 Secured Notes, $~~413.5 million in 2025 Notes, $325.0 million in 2027 Notes, ~~and~~ $325.0 million in 2028 Notes outstanding. The 2024 Secured Notes and the related guarantees are secured by a first priority lien (subject to certain exceptions) on all the fixed assets that secure our obligations under the secured hedge agreements, ~~as governed by the Collateral Trust Agreement, which governs how secured hedging counterparties~~ and ~~holders~~$200.0 ofmillion ~~the~~in ~~2024~~2029 Secured Notes share collateral pledged as security for the payment obligations owed by us to the secured hedging counterparties under their respective master derivatives contracts and the holders of the 2024 Secured Notesoutstanding. In addition, as of ~~September~~March 3031, ~~2023~~2024, we had $~~388~~380.06 million of debt outstanding for our MRL asset financing arrangements, $74.63 million of debt outstanding for our MRL Term Loan Credit Agreement and $5248.79 million of other debt outstanding for the Shreveport terminal asset financing arrangement. Borrowings under the MRL asset financing arrangements and MRL Term Loan Credit Agreement are obligations of our unrestricted subsidiaries MRL and MRHL solely, and are non-recourse to the Company and its restricted subsidiaries.

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

For additional information regarding our senior notes, please read Note 8 — “Long-Term Debt” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” in this Quarterly Report and Note 9 — “Long-Term Debt” in Part II, Item 8 “Financial Statements and Supplementary Data” of our ~~2022~~2023 Annual Report.

Master Derivative Contracts and Collateral Trust Agreement

For additional discussion regarding our master derivative contracts and collateral trust agreement, see “Master Derivative Contracts and Collateral Trust Agreement” under Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our ~~2022~~2023 Annual Report.

~~Critical Accounting Estimates~~50

For additional discussion regarding our critical accounting estimates, see “Critical Accounting Estimates” under Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our 2022 Annual Report.

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Critical Accounting Estimates

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

Commodity Price Risk

Derivative Instruments

We are exposed to price risks due to fluctuations in the price of crude oil, refined products, natural gas and precious metals. We use various strategies to reduce our exposure to commodity price risk. We do not attempt to eliminate all of our risk as the costs of such actions are believed to be too high in relation to the risk posed to our future cash flows, earnings and liquidity. The strategies we use to reduce our risk utilize both physical forward contracts and financially settled derivative instruments, such as swaps, collars, options and futures, to attempt to reduce our exposure with respect to:

●

crude oil purchases and sales;

●

refined product sales and purchases;

●

natural gas purchases;

●

precious metals; and

●

fluctuations in the value of crude oil between geographic regions and between the different types of crude oil such as NYMEX WTI, Light Louisiana Sweet, WCS, WTI Midland, Mixed Sweet Blend, Magellan East Houston and ICE Brent.

We manage our exposure to commodity markets, credit, volumetric and liquidity risks to manage our costs and volatility of cash flows as conditions warrant or opportunities become available. These risks may be managed in a variety of ways that may include the use of derivative instruments. Derivative instruments may be used for the purpose of mitigating risks associated with an asset, liability and anticipated future transactions and the changes in fair value of our derivative instruments will affect our earnings and cash flows; however, such changes should be offset by price or rate changes related to the underlying commodity or financial transaction that is part of the risk management strategy. We do not speculate with derivative instruments or other contractual arrangements that are not associated with our business objectives. Speculation is defined as increasing our natural position above the maximum position of our physical assets or trading in commodities, currencies or other risk bearing assets that are not associated with our business activities and objectives. Our positions are monitored routinely by a risk management committee and discussed with the board of directors of our general partner quarterly to ensure compliance with our stated risk management policy and documented risk management strategies. All strategies are reviewed on an ongoing basis by our risk management committee, which will add, remove or revise strategies in anticipation of changes in market conditions and/or in risk profiles. These changes in strategies are to position us in relation to our risk exposures in an attempt to capture market opportunities as they arise.

Please read Note 9 — “Derivatives” in the notes to our unaudited condensed consolidated financial statements under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” for a discussion of the accounting treatment for the various types of derivative instruments, for a further discussion of our hedging policies and for more information relating to our implied crack spreads of crude oil, diesel, and gasoline derivative instruments.

Our derivative instruments and overall hedging positions are monitored regularly by our risk management committee, which includes executive officers. The risk management committee reviews market information and our hedging positions regularly to determine if additional derivatives activity is advised. A summary of derivative positions and a summary of hedging strategy are presented to our general partner’s Board of Directors quarterly.51

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Compliance Price Risk

Renewable Identification Numbers

We are exposed to market risks related to the volatility in the price of credits needed to comply with governmental programs. The EPA sets annual volume obligations for the percentage of renewable fuels that must be blended into transportation fuels consumed in the U.S., and as a producer of transportation fuels from petroleum, we are subject to those obligations. To the extent we are unable to physically blend renewable fuels to satisfy the EPA requirement, we may purchase RINs in the open market to satisfy the annual obligations. We have not entered into any derivative instruments to manage this risk.

Holding other variables related to RINs obligations constant, a $1.00 increase in the price of RINs would be expected to have a negative impact on Net income (loss) of approximately $65.0 million per year.

Interest Rate Risk

Our exposure to interest rate changes on fixed and variable rate debt is limited to the fair value of the debt issued, which would not have a material impact on our earnings or cash flows. The following table provides information about the fair value of our fixed and variable rate debt obligations as of ~~September~~March 3031, ~~2023~~2024 and December 31, ~~2022~~2023, which we disclose in Note 8 — “Long-Term Debt” and Note 10 — “Fair Value Measurements” under Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements.”


	~~September~~March 3031, ~~2023~~2024				December 31, ~~2022~~2023
	Fair Value		Carrying Value		Fair Value		Carrying Value
	(In millions)
Financial Instrument:
2024 Secured Notes	$	~~179.0~~—	$	~~178.7~~—	$	~~203~~179.7	$	~~199~~178.38
2025 Notes	$	~~421~~413.3	$	411.19	$	~~536~~421.1	$	~~509~~411.25
2027 Notes	$	~~311~~316.39	$	322.15	$	~~305~~320.47	$	~~321~~322.53
2028 Notes	$	~~320~~322.83	$	319.49	$	—325.7	$	—319.7
Revolving credit facility	$	71.1	$	68.6	$	104.0	$	100.9
2029 Secured Notes	$	206.7	$	199.1	$	—	$	—
MRL revolving credit facility	$	—	$	(0.6)	$	—	$	(0.6)
Revolving credit facility	$	309.8	$	306.1	$	136.7	$	134.4
MRL Term Loan Credit Agreement	$	74.6	$	71.7	$	—	$	—
MRL revolving credit facility	$	22.6	$	22.0	$	13.0	$	12.4
Shreveport terminal asset financing arrangement	$	52.7	$	52.0	$	58.2	$	57.2
MRL Term Loan Credit Agreement	$	74.3	$	71.6	$	74.4	$	71.6
MRL asset financing arrangements	$	388.0	$	386.8	$	370.1	$	368.8
Shreveport terminal asset financing arrangement	$	48.9	$	48.4	$	50.8	$	50.1
MRL asset financing arrangements	$	380.6	$	377.7	$	384.6	$	381.6

For our variable rate debt, if any, changes in interest rates generally do not impact the fair value of the debt instrument but may impact our future earnings and cash flows. We had a $~~500~~650.0 million revolving credit facility and a $90.0 million revolving credit facility as of ~~September~~March 3031, ~~2023~~2024, with borrowings for each revolving credit facility bearing interest at the prime rate or SOFR, at our option, plus the applicable margin. In addition, we had $74.63 million of borrowings outstanding under our MRL Term Loan Credit Agreement as of ~~September~~March 3031, ~~2023~~2024, with borrowings bearing interest at SOFR plus 6.0% to 7.3% per annum. We had $~~145~~332.74 million of outstanding variable rate debt as of ~~September~~March 3031, ~~2023~~2024 and $~~104~~149.07 million of outstanding variable rate debt as of December 31, ~~2022~~2023. Holding other variables constant (such as debt levels), a 100 basis point change in interest rates on our variable rate debt as of ~~September~~March 3031, ~~2023~~2024, would be expected to have an impact on Net income (loss) of approximately $13.53 million per year.

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Foreign Currency Risk

We have minimal exposure to foreign currency risk and as such the cost of hedging this risk is viewed to be in excess of the benefit of further reductions in our exposure to foreign currency exchange rate fluctuations.

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Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As required by Rule 13a-15(b) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this Quarterly Report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective as of ~~September~~March 3031, ~~2023~~2024.

Remediation of Previously Reported Material Weakness

As previously disclosed in Part II, Item 9A “Controls and Procedures” in our Annual Report on Form 10-K for the year ended December 31, 2023, we previously identified a material weakness in the design of our internal controls within the financial statement close process associated with the subsequent accounting for and measurement of redeemable noncontrolling interests. This material weakness resulted in material errors in the attribution of Net losses to redeemable noncontrolling interest and the Net losses attributable to partners, which resulted in a restatement of the previously issued financial statements as of and for the year ended December 31, 2022 and as of and for each interim period during the year ended December 31, 2023.

We implemented a plan of remediation engaging with third party resources with technical accounting expertise to strengthen our internal controls over financial reporting which included implementing new controls and increased rigor of financial reporting controls that address subsequent measurement of redeemable noncontrolling interests, including consideration of attribution of income and loss to redeemable noncontrolling interests. Consistent with past practice, preparation and reviews of technical accounting memos will operate for all material non-routine transactions. During the quarter ended March 31, 2024, we completed our testing of the operating effectiveness of internal controls impacted by these remediation efforts and determined that as a result of the measures described above, the material weakness has been remediated as of March 31, 2024.

Changes in Internal Control over Financial Reporting

NoOther than the actions described above, no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) occurred during the fiscal quarter ended ~~September~~March 3031, ~~2023~~2024, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II

Item 1. Legal Proceedings

We are not a party to, and our property is not the subject of, any pending legal proceedings other than ordinary routine litigation incidental to our business. Our operations are subject to a variety of risks and disputes normally incidental to our business. As a result, we may, at any given time, be a defendant in various legal proceedings and litigation arising in the ordinary course of business. The information provided under Note 6 — “Commitments and Contingencies” in Part I, Item 1 “Financial Statements — Notes to Unaudited Condensed Consolidated Financial Statements” is incorporated herein by reference.

Item 1A. Risk Factors

In addition to the other information set forth in this Quarterly Report, you should carefully consider the risks discussed in Part I, Item 1A “Risk Factors” in our ~~2022~~2023 Annual Report. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results. There have been no material changes in the risk factors discussed in Part I, Item 1A “Risk Factors” in our ~~2022~~2023 Annual Report ~~other than with respect to the risk factor discussed below~~.

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

The consummation of the Corporate Reorganization is subject to a number of conditions. The consummation of the Corporate Reorganization is not assured and is subject to risks, including the risk that the unitholder approval of the transaction is not obtained. Further, the Corporate Reorganization may not be consummated even if such unitholder approval is obtained. The Restructuring Agreement contains conditions, some of which are beyond the parties’ control, that, if not satisfied or waived, may prevent, delay or otherwise result in the Corporate Reorganization not being consummated.

If the Corporate Reorganization is not completed, or if there are significant delays in completing the Corporate Reorganization, our future business and financial results and the trading price of our common units could be negatively affected or, following the consummation of the Corporation Reorganization, New Calumet’s future business and financial results and the price of the common stock could be negatively affected, and the parties will be subject to several risks, including the following (i) there may be negative reactions from the financial markets due to the fact that the current price of the common units may reflect a market assumption that the Corporate Reorganization will be completed and (ii) the attention of management will have been diverted to the Corporate Reorganization rather than our own operations and pursuit of other opportunities that could have been beneficial to our business.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

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Item 5. Other Information

~~None~~On March 14, 2024, the Daniel J. Sajkowski 2011 Trust U/DEC DTD 2/8/2011, of which Daniel J. Sajkowski, a member of the board of directors of our general partner, is a co-trustee, adopted a trading plan (the “Plan”) intended to satisfy the affirmative defense of Rule 10b5-1(c) under the Exchange Act. The Plan will commence on March 1, 2025 and will expire on July 31, 2025. The Plan provides for the potential sale of up to 82,000 common units pursuant to the terms of the Plan.

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Item 6. Exhibits


Exhibit Number		Description

2.1		~~Partnership~~Conversion ~~Restructuring~~ Agreement, dated as of ~~November~~February 9, ~~2023~~2024, by and among Calumet Specialty Products Partners, L.P., Calumet GP, LLC, Calumet, Inc., Calumet Merger Sub I LLC, Calumet Merger Sub II LLC and the other parties thereto (incorporated by reference to Exhibit 210.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on ~~November~~February 912, ~~2023~~2024 (File No. 000-51734)).

2.2		First Amendment to Conversion Agreement, dated as of April 17, 2024, by and among Calumet Specialty Products Partners, L.P., Calumet GP, LLC, Calumet, Inc., Calumet Merger Sub I LLC, Calumet Merger Sub II LLC and the other parties thereto (incorporated by reference to Exhibit 2.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on April 19, 2024 (File No. 000-51734)).

2.3		First Amendment to Partnership Restructuring Agreement, dated as of February 9, 2024, by and among Calumet Specialty Products Partners, L.P., Calumet GP, LLC and the other parties thereto (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed with the Commission on February 12, 2024 (File No. 000-51734)).

3.1		Certificate of Limited Partnership of Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 3.1 to the Registrant’s Registration Statement on Form S-1 filed with the Commission on October 7, 2005 (File No. 333-128880)).

3.2		First Amended and Restated Agreement of Limited Partnership of Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on February 13, 2006 (File No. 000-51734)).

3.3		Amendment No. 1 to the First Amended and Restated Agreement of Limited Partnership of Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on July 11, 2006 (File No. 000-51734)).

3.4		Amendment No. 2 to First Amended and Restated Agreement of Limited Partnership of Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on April 18, 2008 (File No. 000-51734)).

3.5		Amendment No. 3 to First Amended and Restated Agreement of Limited Partnership of Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on January 4, 2018 (File No. 000-51734)).

3.6		Certificate of Formation of Calumet GP, LLC (incorporated by reference to Exhibit 3.3 of Registrant’s Registration Statement on Form S-1 filed with the Commission on October 7, 2005 (File No. 333-128880)).

3.7		Amended and Restated Limited Liability Company Agreement of Calumet GP, LLC (incorporated by reference to Exhibit 3.2 to the Registrant’s Current Report on Form 8-K filed with the Commission on February 13, 2006 (File No. 000-51734)).

10.1*		Employment Letter, effective as of September 11, 2023, by and between Calumet GP, LLC and David A. Lunin.
4.1		Indenture, dated March 7, 2024, by and among Calumet Specialty Products Partners, L.P. and Calumet Finance Corp., the guarantors party thereto and Wilmington Trust, National Association, as trustee (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on March 12, 2024 (File No. 000-51734)).

10.2		ISDA 2002 Master Agreement, dated October 3, 2023, by and among Montana Renewables, LLC and Wells Fargo Commodities, LLC (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on October 10, 2023 (File No. 000-51734)).
4.2		Form of 9.25% Senior Secured First Lien Notes due 2029 (included in Exhibit 4.1).

10.3		Schedule to the ISDA 2002 Master Agreement, dated October 3, 2023, by and among Montana Renewables, LLC and Wells Fargo Commodities, LLC (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed with the Commission on October 10, 2023 (File No. 000-51734)).
10.1		Monetization Master Agreement, dated as of January 17, 2024, among J. Aron & Company LLC, Calumet Shreveport Refining, LLC, Calumet Refining, LLC and Calumet Specialty Products Partners, L.P. (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on January 24, 2024 (File No. 000-51734)).

10.4		Credit Support Annex to the Schedule to the ISDA 2002 Master Agreement, dated October 3, 2023, by and among Montana Renewables, LLC and Wells Fargo Commodities, LLC as lender (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed with the Commission on October 10, 2023 (File No. 000-51734)).

10.5		Renewable Fuel and Feedstock Repurchase Master Confirmation, dated October 3, 2023, by and among Montana Renewables, LLC and Wells Fargo Commodities, LLC (incorporated by reference

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		to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed with the Commission on October 10, 2023 (File No. 000-51734)).
10.2		Financing Agreement, dated as of January 17, 2024, among J. Aron & Company LLC, Calumet Shreveport Refining, LLC and Calumet Refining, LLC (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed with the Commission on January 24, 2024 (File No. 000-51734)).

10.6*		Fourth Amendment to Supply and Offtake Agreement, dated as of September 26, 2023, by and between Macquarie Energy North America Trading Inc. and Montana Renewables, LLC.
10.3		Supply and Offtake Agreement, dated as of January 17, 2024, among J. Aron & Company LLC, Calumet Shreveport Refining, LLC and Calumet Refining, LLC (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed with the Commission on January 24, 2024 (File No. 000-51734)).

10.4		Fourth Amendment to Third Amended and Restated Credit Agreement, dated as of January 17, 2024, by and among Calumet Specialty Products Partners, L.P., Bank of America, N.A, and the other parties signatory thereto (incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed with the Commission on January 24, 2024 (File No. 000-51734)).

10.5		Amendment No. 2 to Amended and Restated Collateral Trust Agreement and Second Amended and Restated Security and Pledge Agreement, dated as of March 8, 2024, by and among Calumet Specialty Products Partners, L.P., the obligors party thereto and Wilmington Trust, National Association, as collateral trustee (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed with the Commission on March 12, 2024 (File No. 000-51734)).

31.1*		Sarbanes-Oxley Section 302 certification of Todd Borgmann.

31.2*		Sarbanes-Oxley Section 302 certification of ~~Vincent~~David ~~Donargo~~Lunin.

32.1**		Section 1350 certification of Todd Borgmann and ~~Vincent~~David ~~Donargo~~Lunin.

100.INS*		Inline XBRL Instance Document

101.SCH*		Inline XBRL Taxonomy Extension Schema Document

101.CAL*		Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*		Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*		Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE*		Inline XBRL Taxonomy Extension Presentation Linkbase Document

104*		The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended ~~September~~March 3031, ~~2023~~2024, formatted in Inline XBRL (included within the Exhibit 101 attachments)

*Filed herewith.

**Furnished herewith.

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SIGNATURES

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


	CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

	By:	Calumet GP, LLC, its general partner


Date: November 9, 2023	By:	/s/ Vincent Donargo
Date: May 10, 2024	By:	/s/ David Lunin
		~~Vincent~~David ~~Donargo~~Lunin
		Executive Vice President and Chief Financial Officer of Calumet GP, LLC
		(Authorized Person and Principal Financial Officer)

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