Quarterly Report (10-q)

ALLIANCE RESOURCE PARTNERS 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Table of Contents

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 30, 2021

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

For the transition period from ________________to________________

Commission File No.: 0-26823

ALLIANCE RESOURCE PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

Delaware

73-1564280

(State or other jurisdiction of

incorporation or organization)

(IRS Employer Identification No.)

1717 South Boulder Avenue, Suite 400, Tulsa, Oklahoma 74119

(Address of principal executive offices and zip code)

(918) 295-7600

(Registrant's telephone number, including area code)

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. [X] 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). [X ] 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

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


Title of each class	Trading Symbol	Name of each exchange on which registered
Common units representing limited partner interests	ARLP	NASDAQ Global Select Market

As of November 4, 2021, 127,195,219 common units are outstanding.

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TABLE OF CONTENTS

PART I

FINANCIAL INFORMATION


		Page

ITEM 1.	Financial Statements (Unaudited)
	ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
	Condensed Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020	1
	Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2021 and 2020	2
	Condensed Consolidated Statements of Comprehensive Income (Loss) for the three and nine months ended September 30, 2021 and 2020	3
	Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2021 and 2020	4
	Notes to Condensed Consolidated Financial Statements	5
	1. Organization and Presentation	5
	2. Long-Lived Asset Impairments	6
	3. Goodwill Impairment	6
	4. Contingencies	6
	5. Inventories	7
	6. Fair Value Measurements	7
	7. Long-Term Debt	8
	8. Variable Interest Entities	10
	9. Investment	11
	10. Partners' Capital	11
	11. Revenue from Contracts with Customers	14
	12. Earnings per Limited Partner Unit	15
	13. Workers' Compensation and Pneumoconiosis	15
	14. Common Unit-Based Compensation Plans	16
	15. Components of Pension Plan Net Periodic Benefit Cost	18
	16. Segment Information	18
	17. Subsequent Events	21
ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	22
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	36
ITEM 4.	Controls and Procedures	37
	Forward-Looking Statements	38

PART II
OTHER INFORMATION

ITEM 1.	Legal Proceedings	40
ITEM 1A.	Risk Factors	40
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	40
ITEM 3.	Defaults Upon Senior Securities	40
ITEM 4.	Mine Safety Disclosures	40
ITEM 5.	Other Information	40
ITEM 6.	Exhibits	41

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PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)

(Unaudited)


	September 30,		December 31,
	2021		2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	104,611	$	55,574
Trade receivables		142,007		104,579
Other receivables		1,064		3,481
Inventories, net		65,484		56,407
Advance royalties		2,063		4,168
Prepaid expenses and other assets		10,931		21,565
Total current assets		326,160		245,774
PROPERTY, PLANT AND EQUIPMENT:
Property, plant and equipment, at cost		3,570,201		3,554,090
Less accumulated depreciation, depletion and amortization		(1,873,987)		(1,753,845)
Total property, plant and equipment, net		1,696,214		1,800,245
OTHER ASSETS:
Advance royalties		65,034		56,791
Equity method investments		26,180		27,268
Goodwill		4,373		4,373
Operating lease right-of-use assets		14,338		15,004
Other long-term assets		16,676		16,561
Total other assets		126,601		119,997
TOTAL ASSETS	$	2,148,975	$	2,166,016

LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable	$	70,425	$	47,511
Accrued taxes other than income taxes		23,797		25,054
Accrued payroll and related expenses		39,949		28,524
Accrued interest		12,500		5,132
Workers' compensation and pneumoconiosis benefits		10,635		10,646
Current finance lease obligations		821		766
Current operating lease obligations		1,809		1,854
Other current liabilities		14,379		21,919
Current maturities, long-term debt, net		16,770		73,199
Total current liabilities		191,085		214,605
LONG-TERM LIABILITIES:
Long-term debt, excluding current maturities, net		425,075		519,421
Pneumoconiosis benefits		107,099		105,068
Accrued pension benefit		41,220		46,965
Workers' compensation		43,818		47,521
Asset retirement obligations		122,935		121,487
Long-term finance lease obligations		835		1,458
Long-term operating lease obligations		12,722		13,078
Other liabilities		22,348		24,146
Total long-term liabilities		776,052		879,144
Total liabilities		967,137		1,093,749

COMMITMENTS AND CONTINGENCIES - (NOTE 4)

PARTNERS' CAPITAL:
ARLP Partners' Capital:
Limited Partners - Common Unitholders 127,195,219 units outstanding		1,251,674		1,148,565
Accumulated other comprehensive loss		(80,981)		(87,674)
Total ARLP Partners' Capital		1,170,693		1,060,891
Noncontrolling interest		11,145		11,376
Total Partners' Capital		1,181,838		1,072,267
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$	2,148,975	$	2,166,016

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except unit and per unit data)

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
SALES AND OPERATING REVENUES:
Coal sales	$	362,264	$	335,767	$	975,725	$	886,690
Oil & gas royalties		20,109		9,693		51,222		31,718
Transportation revenues		22,027		6,226		45,153		16,722
Other revenues		11,039		3,965		24,404		26,486
Total revenues		415,439		355,651		1,096,504		961,616

EXPENSES:
Operating expenses (excluding depreciation, depletion and amortization)		233,201		216,027		642,760		637,533
Transportation expenses		22,027		6,226		45,153		16,722
Outside coal purchases		6,065		—		6,179		—
General and administrative		18,655		13,871		51,651		41,131
Depreciation, depletion and amortization		68,763		80,182		192,698		237,662
Asset impairments		—		—		—		24,977
Goodwill impairment		—		—		—		132,026
Total operating expenses		348,711		316,306		938,441		1,090,051

INCOME (LOSS) FROM OPERATIONS		66,728		39,345		158,063		(128,435)

Interest expense (net of interest capitalized for the three and nine months ended September 30, 2021 and 2020 of $123, $199, $314 and $1,265, respectively)		(9,408)		(11,186)		(29,646)		(34,911)
Interest income		19		30		51		112
Equity method investment income		703		62		1,106		650
Other expense		(84)		(723)		(2,632)		(1,456)
INCOME (LOSS) BEFORE INCOME TAXES		57,958		27,528		126,942		(164,040)

INCOME TAX EXPENSE		234		293		227		111

NET INCOME (LOSS)		57,724		27,235		126,715		(164,151)

LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST		(176)		(36)		(384)		(97)

NET INCOME (LOSS) ATTRIBUTABLE TO ARLP	$	57,548	$	27,199	$	126,331	$	(164,248)

EARNINGS PER LIMITED PARTNER UNIT - BASIC AND DILUTED	$	0.44	$	0.21	$	0.97	$	(1.29)

WEIGHTED-AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED		127,195,219		127,195,219		127,195,219		127,154,398

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

(Unaudited)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

NET INCOME (LOSS)	$	57,724	$	27,235	$	126,715	$	(164,151)

OTHER COMPREHENSIVE INCOME (LOSS):

Defined benefit pension plan
Amortization of prior service cost (1)		47		47		140		140
Amortization of net actuarial loss (1)		1,141		969		3,424		3,096
Total defined benefit pension plan adjustments		1,188		1,016		3,564		3,236

Pneumoconiosis benefits
Amortization of net actuarial loss (gain) (1)		1,043		(172)		3,129		(515)
Total pneumoconiosis benefits adjustments		1,043		(172)		3,129		(515)

OTHER COMPREHENSIVE INCOME		2,231		844		6,693		2,721

COMPREHENSIVE INCOME (LOSS)		59,955		28,079		133,408		(161,430)

Less: Comprehensive income attributable to noncontrolling interest		(176)		(36)		(384)		(97)

COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO ARLP	$	59,779	$	28,043	$	133,024	$	(161,527)

(1)	Amortization of prior service cost and net actuarial gain or loss is included in the computation of net periodic benefit cost (see Notes 13 and 15 for additional details).

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Nine Months Ended
	September 30,
	2021		2020

CASH FLOWS FROM OPERATING ACTIVITIES	$	310,977	$	291,788

CASH FLOWS FROM INVESTING ACTIVITIES:
Property, plant and equipment:
Capital expenditures		(88,661)		(102,820)
Change in accounts payable and accrued liabilities		2,281		(9,698)
Proceeds from sale of property, plant and equipment		6,432		2,750
Distributions received from investments in excess of cumulative earnings		1,088		841
Escrow deposit for oil & gas reserve acquisition		(1,550)		—
Net cash used in investing activities		(80,410)		(108,927)

CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under securitization facility		35,000		46,100
Payments under securitization facility		(90,900)		(47,700)
Proceeds from equipment financings		—		14,705
Payments on equipment financings		(12,888)		(10,622)
Borrowings under revolving credit facilities		15,000		70,000
Payments under revolving credit facilities		(102,500)		(190,000)
Borrowings from line of credit		3,230		—
Payments on finance lease obligations		(568)		(8,204)
Payment of debt issuance costs		(113)		(5,821)
Payments for purchase of units and tax withholdings related to settlements under deferred compensation plans		(1,090)		(1,310)
Distributions paid to Partners		(26,086)		(51,753)
Other		(615)		(603)
Net cash used in financing activities		(181,530)		(185,208)
NET CHANGE IN CASH AND CASH EQUIVALENTS		49,037		(2,347)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		55,574		36,482
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	104,611	$	34,135

SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest	$	20,045	$	26,686
Cash paid for income taxes	$	11	$	10

SUPPLEMENTAL NON-CASH ACTIVITY:
Accounts payable for purchase of property, plant and equipment	$	8,012	$	4,806
Right-of-use assets acquired by operating lease	$	—	$	278
Market value of common units issued under deferred compensation plans before tax withholding requirements	$	1,082	$	3,837

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.ORGANIZATION AND PRESENTATION

Significant Relationships Referenced in Notes to Condensed Consolidated Financial Statements

●

References to "we," "us," "our" or "ARLP Partnership" mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.

●

References to "ARLP" mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.

●

References to "MGP" mean Alliance Resource Management GP, LLC, ARLP's general partner.

●

References to "Mr. Craft" mean Joseph W. Craft III, the Chairman, President and Chief Executive Officer of MGP.

●

References to "Intermediate Partnership" mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P.

●

References to "Alliance Coal" mean Alliance Coal, LLC, the holding company for our coal mining operations.

●

References to "Alliance Minerals" mean Alliance Minerals, LLC, the holding company for our oil and gas minerals interests.

●

References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, the land holding company for certain of our coal mineral interests, including the subsidiaries of Alliance Resource Properties, LLC.

Organization

ARLP is a Delaware limited partnership listed on the NASDAQ Global Select Market under the ticker symbol "ARLP." ARLP was formed in May 1999 and completed its initial public offering on August 19, 1999 when it acquired substantially all of the coal production and marketing assets of Alliance Resource Holdings, Inc., a Delaware corporation, and its subsidiaries. We are managed by our general partner, MGP, a Delaware limited liability company which holds a non-economic general partner interest in ARLP.

Basis of Presentation

The accompanying condensed consolidated financial statements include the accounts and operations of the ARLP Partnership and present our financial position as of September 30, 2021 and December 31, 2020, the results of our operations and comprehensive income (loss) for the three and nine months ended September 30, 2021 and 2020, and cash flows for the nine months ended September 30, 2021 and 2020. All intercompany transactions and accounts have been eliminated.

These condensed consolidated financial statements and notes are prepared pursuant to the rules and regulations of the Securities and Exchange Commission for interim reporting and do not include all the information normally included with financial statements prepared in accordance with generally accepted accounting principles ("GAAP") of the United States. These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2020.

These condensed consolidated financial statements and notes are unaudited. However, in the opinion of management, these condensed consolidated financial statements reflect all normal recurring adjustments necessary for a fair presentation of the results for the periods presented. Results for interim periods are not necessarily indicative of results to be expected for the full year ending December 31, 2021.

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Use of Estimates

The preparation of the ARLP Partnership's condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosures in our condensed consolidated financial statements. Actual results could differ from those estimates.

2.LONG-LIVED ASSET IMPAIRMENTS

During the first quarter of 2020, we recorded $23.5 million of non-cash asset impairment charges in our Illinois Basin Coal Operations segment due to sealing our idled Gibson North mine, resulting in its permanent closure, and a decrease in the fair value of certain mining equipment at our idled operations and greenfield coal reserves as a result of weakened coal market conditions. During the same period, we also recorded an asset impairment charge of $1.5 million in our Coal Royalties segment due to a decrease in the fair value of greenfield coal reserves held by Alliance Resource Properties near our coal mining operations in the Illinois Basin. See Note 16 – Segment Information for more information about our segments.

The fair values of the impaired assets were determined using a market approach, which represents Level 3 fair value measurements under the fair value hierarchy. The fair value analysis used assumptions regarding the marketability of certain mining and reserve assets near our Illinois Basin coal mining operations.

3.GOODWILL IMPAIRMENT

During the first quarter of 2020, we considered whether an interim test of our consolidated goodwill of $136.4 million was necessary. Our consolidated goodwill included $132.0 million recorded in our Illinois Basin Coal Operations segment in conjunction with our acquisition of the Hamilton County Coal, LLC ("Hamilton") mine on July 31, 2015. We assessed certain events and changes in circumstances, including a) adverse industry and market developments, including the impact of the COVID-19 pandemic, b) our response to these developments, including temporarily ceasing production at several mines, including our Hamilton mine and c) our actual performance during the quarter. After consideration of these events and changes in circumstances, we performed an interim test of the goodwill associated with Hamilton comparing Hamilton's carrying amount to its fair value.

We estimated the fair value of Hamilton using an income approach utilizing a discounted cash flow model. The assumptions used in the discounted cash flow model included estimated production, forward coal prices, operating expenses, capital expenditures and a weighted average cost of capital. Our forecasts of future cash flows considered market conditions at the time of the assessment and our estimate of the mine's performance in future years based on the information available to us. Key assumptions used in our valuation were not observable in active markets; therefore, the fair value measurements represent Level 3 fair value measurements. The fair value of Hamilton was determined to be below its carrying amount (including goodwill) by more than the recorded balance of goodwill associated with the mine. Accordingly, we recognized an impairment charge of $132.0 million consisting of the total carrying amount of goodwill associated with Hamilton. This impairment charge reduced our consolidated goodwill balance to $4.4 million. During the first quarter of 2020, we also performed an interim test on ARLP's remaining goodwill balances not associated with Hamilton and concluded no impairment was necessary for our other reporting units.

4.CONTINGENCIES

We are party to litigation that has been initiated against certain of our subsidiaries in which the plaintiffs allege violations of the Fair Labor Standards Act and Kentucky Wage and Hour Act due to an alleged failure to compensate for time "donning" and "doffing" equipment and to account for certain bonuses in the calculation of overtime rates and pay. The plaintiffs seek class or collective action certification. Because the litigation of these matters is in the early stages, we cannot reasonably estimate a range of potential exposure at this time. We believe the plaintiffs’ claims are without merit and our ultimate exposure, if any, will not be material to our results of operations or financial position and we intend to defend the litigation vigorously. However, if our current belief that the claims are without merit is not upheld, it is reasonably possible that the ultimate resolution of these matters could result in a potential loss that may be material to our results of operations.

We also have various other lawsuits, claims and regulatory proceedings incidental to our business that are pending against the ARLP Partnership. We record an accrual for a potential loss related to these matters when, in management's

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opinion, such loss is probable and reasonably estimable. Based on known facts and circumstances, we believe the ultimate outcome of these outstanding lawsuits, claims and regulatory proceedings will not have a material adverse effect on our financial condition, results of operations or liquidity. However, if the results of these matters are different from management's current expectations and in amounts greater than our accruals, such matters could have a material adverse effect on our business and operations.

5.INVENTORIES

Inventories consist of the following:


	September 30,		December 31,
	2021		2020

	(in thousands)

Coal	$	31,066	$	19,756
Supplies (net of reserve for obsolescence of $5,554 and $5,547, respectively)		34,418		36,651
Total inventories, net	$	65,484	$	56,407

6.FAIR VALUE MEASUREMENTS

The following table summarizes our fair value measurements within the hierarchy not included elsewhere in these notes:


	September 30, 2021						December 31, 2020
	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3

	(in thousands)
Long-term debt	$	—	$	459,650	$	—	$	—	$	518,317	$	—
Total	$	—	$	459,650	$	—	$	—	$	518,317	$	—

The carrying amounts for cash equivalents, accounts receivable, accounts payable, accrued and other liabilities approximate fair value due to the short maturity of those instruments.

The estimated fair value of our long-term debt, including current maturities, is based on interest rates that we believe are currently available to us in active markets for issuance of debt with similar terms and remaining maturities (See Note 7 – Long-Term Debt). The fair value of debt, which is based upon these interest rates, is classified as a Level 2 measurement under the fair value hierarchy.

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7.LONG-TERM DEBT

Long-term debt consists of the following:


					Unamortized Discount and
	Principal				Debt Issuance Costs
	September 30,		December 31,		September 30,		December 31,
	2021		2020		2021		2020

	(in thousands)
Revolving credit facility	$	—	$	87,500	$	(5,599)	$	(7,196)
Senior notes		400,000		400,000		(3,278)		(3,964)
Securitization facility		—		55,900		—		—
May 2019 equipment financing		2,387		4,956		—		—
November 2019 equipment financing		34,617		42,367		—		—
June 2020 equipment financing		10,488		13,057		—		—
Line of credit		3,230		—		—		—
		450,722		603,780		(8,877)		(11,160)
Less current maturities		(16,770)		(73,199)		—		—
Total long-term debt	$	433,952	$	530,581	$	(8,877)	$	(11,160)

Credit Facility. On March 9, 2020, our Intermediate Partnership entered into a Fifth Amended and Restated Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $459.5 million revolving credit facility, including a sublimit of $125 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings (the "Revolving Credit Facility"), with a termination date of March 9, 2024.

The Credit Agreement is guaranteed by certain of our Intermediate Partnership's material direct and indirect subsidiaries (the "Restricted Subsidiaries") and is secured by substantially all the assets of the Restricted Subsidiaries. The Credit Agreement is also guaranteed by Alliance Minerals but the oil and gas minerals assets of Alliance Minerals and its direct and indirect subsidiaries (collectively with Alliance Minerals, the "Unrestricted Subsidiaries") are not collateral under the Credit Agreement. Borrowings under the Revolving Credit Facility bear interest, at our option, at either (i) the Base Rate at the greater of three benchmarks or (ii) a Eurodollar Rate, plus margins for (i) or (ii), as applicable, that fluctuate depending upon the ratio of Consolidated Debt to Consolidated Cash Flow (each as defined in the Credit Agreement). The Eurodollar Rate, with applicable margin, under the Revolving Credit Facility was 2.68% as of September 30, 2021. On September 30, 2021, we had $23.3 million of letters of credit outstanding with $436.2 million available for borrowing under the Revolving Credit Facility. We incur an annual commitment fee of 0.35% on the undrawn portion of the Revolving Credit Facility. We utilize the Revolving Credit Facility, as appropriate, for working capital requirements, capital expenditures and investments, scheduled debt payments and distribution payments.

The Credit Agreement contains various restrictions affecting the Intermediate Partnership and its Restricted Subsidiaries including, among other things, restrictions on incurrence of additional indebtedness and liens, sale of assets, investments, mergers and consolidations and transactions with affiliates, including transactions with Unrestricted Subsidiaries. In each case, these restrictions are subject to various exceptions. In addition, the payment of cash distributions is restricted if such payment would result in a fixed charge coverage ratio of less than 1.0 to 1.0 (as defined in the Credit Agreement) for the four most recently ended fiscal quarters. The Credit Agreement requires the Intermediate Partnership to maintain (a) a debt to cash flow ratio of not more than 2.5 to 1.0, (b) a cash flow to interest expense ratio of not less than 3.0 to 1.0 and (c) a first lien debt to cash flow ratio of not more than 1.5 to 1.0, in each case, during the four most recently ended fiscal quarters. The debt to cash flow ratio, cash flow to interest expense ratio and first lien debt to cash flow ratio were 0.95 to 1.0, 11.60 to 1.0 and 0.10 to 1.0, respectively, for the trailing twelve months ended September 30, 2021. We remained in compliance with the covenants of the Credit Agreement as of September 30, 2021 and anticipate remaining in compliance with the covenants.

Senior Notes. On April 24, 2017, the Intermediate Partnership and Alliance Resource Finance Corporation (as co-issuer), a wholly owned subsidiary of the Intermediate Partnership ("Alliance Finance"), issued an aggregate principal amount of $400.0 million of senior unsecured notes due 2025 ("Senior Notes") in a private placement to qualified institutional buyers. The Senior Notes have a term of eight years, maturing on May 1, 2025 (the "Term") and accrue interest at an annual rate of 7.5%. Interest is payable semi-annually in arrears on each May 1 and November 1. The

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indenture governing the Senior Notes contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of distributions or similar restricted payments, undertaking transactions with affiliates and limitations on asset sales. The issuers of the Senior Notes may redeem all or a part of the notes at any time at redemption prices set forth in the indenture governing the Senior Notes.

Accounts Receivable Securitization. On December 5, 2014, certain direct and indirect wholly owned subsidiaries of our Intermediate Partnership entered into a $100.0 million accounts receivable securitization facility ("Securitization Facility"). Under the Securitization Facility, certain subsidiaries sell certain trade receivables on an ongoing basis to our Intermediate Partnership, which then sells the trade receivables to AROP Funding, LLC ("AROP Funding"), a wholly owned bankruptcy-remote special purpose subsidiary of our Intermediate Partnership, which in turn borrows on a revolving basis up to $100.0 million secured by the trade receivables. After the sale, Alliance Coal, as servicer of the assets, collects the receivables on behalf of AROP Funding. The Securitization Facility bears interest based on a Eurodollar Rate. The agreement governing the Securitization Facility contains customary terms and conditions, including limitations with regards to certain customer credit ratings. In January 2021, we extended the term of the Securitization Facility to January 2022 and reduced the borrowing availability under the facility to $60.0 million. The Securitization Facility was previously scheduled to mature in January 2021. On September 30, 2021, we had no outstanding balance under the Securitization Facility.

May 2019 Equipment Financing. On May 17, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $10.0 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "May 2019 Equipment Financing"). The May 2019 Equipment Financing contains customary terms and events of default and provides for thirty-six monthly payments with an implicit interest rate of 6.25%, maturing on May 1, 2022. Upon maturity, the equipment will revert to the Intermediate Partnership.

November 2019 Equipment Financing. On November 6, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $53.1 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "November 2019 Equipment Financing"). The November 2019 Equipment Financing contains customary terms and events of default and an implicit interest rate of 4.75%, providing for a four-year term with forty-seven monthly payments of $1.0 million and a balloon payment of $11.6 million upon maturity on November 6, 2023. Upon maturity, the equipment will revert to the Intermediate Partnership.

June 2020 Equipment Financing. On June 5, 2020, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $14.7 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "June 2020 Equipment Financing"). The June 2020 Equipment Financing contains customary terms and events of default and provides for forty-eight monthly payments with an implicit interest rate of 6.1%, maturing on June 5, 2024. Upon maturity, the equipment will revert to the Intermediate Partnership.

Line of Credit. On February 19, 2021, we entered into a line of credit arrangement with a related party for $5.0 million. The line of credit has a maturity date of February 28, 2023, with an option to extend it for an additional six months and accrue interest at an annual rate of 3.50%. Interest is payable quarterly commencing March 31, 2021, and continuing each March 31, June 30, September 30 and December 31 thereafter through and including February 28, 2023. The agreement contains customary terms and events of default and is guaranteed by ARLP. We utilize the line of credit, as appropriate, for capital expenditures and investments. As of September 30, 2021, we had drawn $3.2 million under this agreement.

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8.VARIABLE INTEREST ENTITIES

Cavalier Minerals

On November 10, 2014, our subsidiary, Alliance Minerals, and Bluegrass Minerals Management, LLC ("Bluegrass Minerals") entered into a limited liability company agreement (the "Cavalier Agreement") to create Cavalier Minerals JV, LLC ("Cavalier Minerals"), which was formed to indirectly acquire oil & gas mineral interests through its ownership in AllDale Minerals LP ("AllDale I") and AllDale Minerals II, LP ("AllDale II", and collectively with AllDale I, "AllDale I & II"). Alliance Minerals owns a 96% member interest in Cavalier Minerals, and Bluegrass Minerals owns a 4% member interest in Cavalier Minerals and a profits interest which entitles it to receive distributions equal to 25% of all distributions (including in liquidation) after all members have recovered their investment. Distributions with respect to Bluegrass Minerals' profits interest will be offset by all distributions received by Bluegrass Minerals from the former general partners of AllDale I & II. To date, there has been no profits interest distribution. We hold the managing member interest in Cavalier Minerals. Total contributions to and cumulative distributions from Cavalier Minerals are as follows:


	Alliance		Bluegrass
	Minerals		Minerals
	(in thousands)
Contributions	$	143,112	$	5,963
Distributions		104,149		4,339

We have concluded that Cavalier Minerals is a variable interest entity ("VIE") which we consolidate as the primary beneficiary because we are the managing member and a substantial equity owner in Cavalier Minerals. Bluegrass Minerals' equity ownership of Cavalier Minerals is accounted for as noncontrolling ownership interest in our condensed consolidated balance sheets. In addition, earnings attributable to Bluegrass Minerals are recognized as noncontrolling interest in our condensed consolidated statements of operations.

AllDale III

In February 2017, Alliance Minerals committed to directly invest $30.0 million in AllDale Minerals III, LP ("AllDale III") which was created for similar investment purposes as AllDale I & II. Alliance Minerals completed funding of this commitment in 2018. Alliance Minerals' limited partner interest in AllDale III is 13.9%.

The AllDale III Partnership Agreement includes a 25% profits interest for the general partner, subject to a return hurdle equal to the greater of 125% of cumulative capital contributions and a 10% internal rate of return, and following an 80/20 "catch-up" provision for the general partner.

Since AllDale III is structured as a limited partnership with the limited partners 1) not having the ability to remove the general partner and 2) not participating significantly in the operational decisions, we concluded that AllDale III is a VIE. We are not the primary beneficiary of AllDale III as we do not have the power to direct the activities that most significantly impact AllDale III's economic performance. We account for our ownership interest in the income or loss of AllDale III as an equity method investment. We record equity income or loss based on AllDale III's distribution structure. See Note 9 – Investment for more information.

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9.INVESTMENT

AllDale III

As discussed in Note 8 – Variable Interest Entities, we account for our ownership interest in the income or loss of AllDale III as an equity method investment. We record equity income or loss based on AllDale III's distribution structure. The changes in our equity method investment in AllDale III for each of the periods presented were as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Beginning balance	$	26,274	$	27,705	$	27,268	$	28,529
Equity method investment income		703		62		1,106		650
Distributions received		(797)		(352)		(2,194)		(1,491)
Other		—		—		—		(273)
Ending balance	$	26,180	$	27,415	$	26,180	$	27,415

10.PARTNERS' CAPITAL

Distributions

Distributions paid or declared during 2020 and 2021 were as follows:


Payment Date	Per Unit Cash Distribution		Total Cash Distribution
			(in thousands)

February 14, 2020	$	0.4000	$	51,753
Total	$	0.4000	$	51,753

May 14, 2021	$	0.1000	$	13,045
August 13, 2021		0.1000		13,041
November 12, 2021 (1)		0.2000		—
Total	$	0.4000	$	26,086

(1)	On October 25, 2021, we declared this quarterly distribution payable on November 12, 2021 to all unitholders of record as of November 5, 2021.

Unit Repurchase Program

In May 2018, the MGP board of directors approved the establishment of a unit repurchase program authorizing us to repurchase and retire up to $100 million of ARLP common units. The program has no time limit and we may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate us to repurchase any dollar amount or number of units. No unit repurchases were made during the nine months ended September 30, 2021. Since inception of the unit repurchase program, we have repurchased and retired 5,460,639 units at an average unit price of $17.12 for an aggregate purchase price of $93.5 million. The remaining authorized amount for unit repurchases under this program is $6.5 million.

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Change in Partners' Capital

The following tables present the quarterly change in Partners' Capital for the nine months ended September 30, 2021 and 2020:


				Accumulated
	Number of	Limited		Other
	Limited Partner	Partners'		Comprehensive		Noncontrolling		Total Partners'
	Units	Capital		Income (Loss)		Interest		Capital

	(in thousands, except unit data)
Balance at January 1, 2021	127,195,219	$	1,148,565	$	(87,674)	$	11,376	$	1,072,267
Comprehensive income:
Net income	—		24,748		—		78		24,826
Actuarially determined long-term liability adjustments	—		—		2,231		—		2,231
Total comprehensive income									27,057
Common unit-based compensation	—		723		—		—		723
Distributions from consolidated company to noncontrolling interest	—		—		—		(141)		(141)
Balance at March 31, 2021	127,195,219		1,174,036		(85,443)		11,313		1,099,906
Comprehensive income:
Net income	—		44,035		—		130		44,165
Actuarially determined long-term liability adjustments	—		—		2,231		—		2,231
Total comprehensive income									46,396
Common unit-based compensation	—		1,485		—		—		1,485
Distributions on deferred common unit-based compensation	—		(324)		—		—		(324)
Distributions from consolidated company to noncontrolling interest	—		—		—		(222)		(222)
Distributions to Partners	—		(12,721)		—		—		(12,721)
Balance at June 30, 2021	127,195,219		1,206,511		(83,212)		11,221		1,134,520
Comprehensive income:
Net income	—		57,548		—		176		57,724
Actuarially determined long-term liability adjustments	—		—		2,231		—		2,231
Total comprehensive income									59,955
Settlement of deferred compensation plans			(1,090)		—		—		(1,090)
Common unit-based compensation	—		1,746		—		—		1,746
Distributions on deferred common unit-based compensation	—		(323)		—		—		(323)
Distributions from consolidated company to noncontrolling interest	—		—		—		(252)		(252)
Distributions to Partners	—		(12,718)		—		—		(12,718)
Balance at September 30, 2021	127,195,219	$	1,251,674	$	(80,981)	$	11,145	$	1,181,838

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				Accumulated
	Number of	Limited		Other
	Limited Partner	Partners'		Comprehensive		Noncontrolling		Total Partners'
	Units	Capital		Income (Loss)		Interest		Capital

	(in thousands, except unit data)
Balance at January 1, 2020	126,915,597	$	1,331,482	$	(77,993)	$	11,935	$	1,265,424
Comprehensive income (loss):
Net income (loss)	—		(144,783)		—		76		(144,707)
Actuarially determined long-term liability adjustments	—		—		938		—		938
Total comprehensive loss									(143,769)
Settlement of deferred compensation plans	279,622		(1,310)		—		—		(1,310)
Common unit-based compensation	—		(527)		—		—		(527)
Distributions on deferred common unit-based compensation	—		(986)		—		—		(986)
Distributions from consolidated company to noncontrolling interest	—		—		—		(288)		(288)
Distributions to Partners	—		(50,767)		—		—		(50,767)
Other	—		(273)		—		—		(273)
Balance at March 31, 2020	127,195,219		1,132,836		(77,055)		11,723		1,067,504
Comprehensive income (loss):
Net loss	—		(46,664)		—		(15)		(46,679)
Actuarially determined long-term liability adjustments	—		—		939		—		939
Total comprehensive loss									(45,740)
Common unit-based compensation	—		1,610		—		—		1,610
Distributions from consolidated company to noncontrolling interest	—		—		—		(222)		(222)
Balance at June 30, 2020	127,195,219		1,087,782		(76,116)		11,486		1,023,152
Comprehensive income:
Net income	—		27,199		—		36		27,235
Actuarially determined long-term liability adjustments	—		—		844		—		844
Total comprehensive income									28,079
Common unit-based compensation	—		1,645		—		—		1,645
Distributions from consolidated company to noncontrolling interest	—		—		—		(93)		(93)
Balance at September 30, 2020	127,195,219	$	1,116,626	$	(75,272)	$	11,429	$	1,052,783

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11.REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table illustrates the disaggregation of our revenues by type, including a reconciliation to our segment presentation as presented in Note 16 – Segment Information.


	Coal Operations				Royalties				Other,
	Illinois								Corporate and
	Basin		Appalachia		Oil & Gas		Coal		Elimination		Consolidated

	(in thousands)
Three Months Ended September 30, 2021

Coal sales	$	217,637	$	144,627	$	—	$	—	$	—	$	362,264
Oil & gas royalties		—		—		20,109		—		—		20,109
Coal royalties		—		—		—		13,456		(13,456)		—
Transportation revenues		12,121		9,906		—		—		—		22,027
Other revenues		1,335		411		1,082		—		8,211		11,039
Total revenues	$	231,093	$	154,944	$	21,191	$	13,456	$	(5,245)	$	415,439

Three Months Ended September 30, 2020

Coal sales	$	206,356	$	129,411	$	—	$	—	$	—	$	335,767
Oil & gas royalties		—		—		9,693		—		—		9,693
Coal royalties		—		—		—		11,406		(11,406)		—
Transportation revenues		3,722		2,504		—		—		—		6,226
Other revenues		241		395		28		42		3,259		3,965
Total revenues	$	210,319	$	132,310	$	9,721	$	11,448	$	(8,147)	$	355,651

Nine Months Ended September 30, 2021

Coal sales	$	610,435	$	365,290	$	—	$	—	$	—	$	975,725
Oil & gas royalties		—		—		51,222		—		—		51,222
Coal royalties		—		—		—		36,410		(36,410)		—
Transportation revenues		27,235		17,918		—		—		—		45,153
Other revenues		2,590		1,078		1,576		—		19,160		24,404
Total revenues	$	640,260	$	384,286	$	52,798	$	36,410	$	(17,250)	$	1,096,504

Nine Months Ended September 30, 2020

Coal sales	$	539,614	$	347,076	$	—	$	—	$	—	$	886,690
Oil & gas royalties		—		—		31,718		—		—		31,718
Coal royalties		—		—		—		29,555		(29,555)		—
Transportation revenues		10,731		5,991		—		—		—		16,722
Other revenues		1,633		14,456		113		47		10,237		26,486
Total revenues	$	551,978	$	367,523	$	31,831	$	29,602	$	(19,318)	$	961,616

The following table illustrates the amount of our transaction price for all current coal supply contracts allocated to performance obligations that are unsatisfied or partially unsatisfied as of September 30, 2021 and disaggregated by segment and contract duration.


							2024 and
	2021		2022		2023		Thereafter		Total

	(in thousands)

Illinois Basin Coal Operations coal revenues	$	293,651	$	567,699	$	255,470	$	196,683	$	1,313,503
Appalachia Coal Operations coal revenues		183,060		325,846		17,880		10,080		536,866
Total coal revenues (1)	$	476,711	$	893,545	$	273,350	$	206,763	$	1,850,369

(1) Coal revenues generally consists of consolidated revenues excluding our Oil & Gas Royalties segment as well as intercompany revenues from our Coal Royalties segment.

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12.EARNINGS PER LIMITED PARTNER UNIT

We utilize the two-class method in calculating basic and diluted earnings per limited partner unit ("EPU"). Net income attributable to ARLP is allocated to limited partners and participating securities under deferred compensation plans, which include rights to nonforfeitable distributions or distribution equivalents. Net losses attributable to ARLP are allocated to limited partners but not to participating securities. Our participating securities are outstanding restricted unit awards under our Long-Term Incentive Plan ("LTIP") and phantom units in notional accounts under our Supplemental Executive Retirement Plan ("SERP") and the MGP Amended and Restated Deferred Compensation Plan for Directors ("Directors' Deferred Compensation Plan").

The following is a reconciliation of net income (loss) attributable to ARLP used for calculating basic and diluted earnings per unit and the weighted-average units used in computing EPU for the three and nine months ended September 30, 2021 and 2020:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands, except per unit data)
Net income (loss) attributable to ARLP	$	57,548	$	27,199	$	126,331	$	(164,248)

Less:
Distributions to participating securities		(765)		—		(1,384)		—
Undistributed earnings attributable to participating securities		(951)		(581)		(1,832)		—

Net income (loss) attributable to ARLP available to limited partners	$	55,832	$	26,618	$	123,115	$	(164,248)

Weighted-average limited partner units outstanding – basic and diluted		127,195		127,195		127,195		127,154

Earnings per limited partner unit - basic and diluted (1)	$	0.44	$	0.21	$	0.97	$	(1.29)

(1)

Diluted EPU gives effect to all potentially dilutive common units outstanding during the period using the treasury stock method. Diluted EPU excludes all potentially dilutive units calculated under the treasury stock method if their effect is anti-dilutive. The combined total of LTIP, SERP and Directors' Deferred Compensation Plan units of 2,328 and 1,706 for the three and nine months ended September 30, 2021, respectively, and 661 and 656 for the three and nine months ended September 30, 2020, respectively, were considered anti-dilutive under the treasury stock method.

13.WORKERS' COMPENSATION AND PNEUMOCONIOSIS

The changes in the workers' compensation liability, including current and long-term liability balances, for each of the periods presented were as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Beginning balance	$	52,059	$	54,478	$	54,739	$	53,384
Accruals increase		1,674		1,599		4,911		3,539
Payments		(2,939)		(2,123)		(7,914)		(6,686)
Interest accretion		232		319		695		958
Valuation loss (gain) (1)		—		—		(1,405)		3,078
Ending balance	$	51,026	$	54,273	$	51,026	$	54,273

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(1)

Our estimate of the liability for the present value of current workers′ compensation benefits is based on our actuarial calculations. Our actuarial calculations are based on a blend of actuarial projection methods and numerous assumptions including claims development patterns, mortality, medical costs and interest rates. The valuation gain in 2021 is due to an increase in the discount rate from 1.95% on December 31, 2020 to 2.34% on June 30, 2021. We conducted a mid-year 2020 review of our actuarial assumptions, which resulted in a valuation loss in 2020 due to unfavorable changes in claims development and a decrease in the discount rate from 2.81% on December 31, 2019 to 2.05% on June 30, 2020.

We limit our exposure to traumatic injury claims by purchasing a high deductible insurance policy that starts paying benefits after deductibles for a claim have been met. The deductible level may vary by claim year. Our workers' compensation liability above is presented on a gross basis and does not include our expected receivables on our insurance policy. Our receivables for traumatic injury claims under this policy as of September 30, 2021 are $7.1 million and are included in Other long-term assets on our condensed consolidated balance sheet.

Certain of our mine operating entities are liable under state statutes and the Federal Coal Mine Health and Safety Act of 1969, as amended, to pay pneumoconiosis, or black lung, benefits to eligible employees and former employees and their dependents. Components of the net periodic benefit cost for each of the periods presented are as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Service cost	$	1,007	$	882	$	3,027	$	2,643
Interest cost (1)		636		750		1,909		2,249
Net amortization (1)		1,043		(172)		3,129		(515)
Net periodic benefit cost	$	2,686	$	1,460	$	8,065	$	4,377

(1)	Interest cost and net amortization are included in the Other expense line item within our condensed consolidated statements of operations.

14.COMMON UNIT-BASED COMPENSATION PLANS

Long-Term Incentive Plan

We maintain the LTIP for certain employees and officers of MGP and its affiliates who perform services for us. As part of our LTIP, unit awards of non-vested "phantom" or notional units, also referred to as "restricted units", may be granted which upon satisfaction of time and performance-based vesting requirements, entitle the LTIP participant to receive ARLP common units. Certain awards may also contain a minimum-value guarantee payable in ARLP common units or cash that would be paid regardless of whether or not the awards vest, as long as service requirements are met. Annual grant levels, vesting provisions and minimum-value guarantees of restricted units for designated participants are recommended by Mr. Craft, subject to review and approval of the compensation committee of the MGP board of directors (the "Compensation Committee"). Vesting of all restricted units outstanding is subject to the satisfaction of certain financial tests. If it is not probable the financial tests for a particular grant of restricted units will be met, any previously expensed amounts for that grant are reversed and no future expense will be recognized for that grant. Assuming the financial tests are met, grants of restricted units issued to LTIP participants are generally expected to cliff vest on January 1st of the third year following issuance of the grants. We expect to settle restricted unit grants by delivery of newly-issued ARLP common units, except for the portion of the grants that will satisfy employee tax withholding obligations of LTIP participants. We account for forfeitures of non-vested LTIP restricted unit grants as they occur. As provided under the distribution equivalent rights ("DERs") provisions of the LTIP and the terms of the LTIP restricted unit awards, all non-vested restricted units include contingent rights to receive quarterly distributions in cash or, at the discretion of the Compensation Committee, phantom units in lieu of cash credited to a bookkeeping account with value equal to the cash distributions we make to unitholders during the vesting period. If it is not probable the financial tests for a particular grant of restricted units will be met, any previously paid DER amounts for that grant are reversed from Partners’ Capital and recorded as compensation expense and any future DERs, for that grant, if any, will be recognized as compensation expense when paid.

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A summary of non-vested LTIP grants as of and for the nine months ended September 30, 2021 is as follows:


	Number of units	Weighted average grant date fair value per unit		Intrinsic value
				(in thousands)

Non-vested grants at January 1, 2021	1,430,489	$	5.02	$	6,409
Granted (1)	1,818,190		6.03
Forfeited	(69,933)		5.46
Non-vested grants at September 30, 2021	3,178,746		5.59		34,553

(1)	921,430 units and 896,760 units have a minimum-value guarantee of $2.53 and $3.79 per unit, respectively, regardless of whether or not the awards vest.

LTIP expense for grants of restricted units was $1.7 million and $1.6 million for the three months ended September 30, 2021 and 2020, respectively, and $3.8 million and $2.5 million for the nine months ended September 30, 2021 and 2020, respectively. LTIP expense for grants of restricted units for the nine months ended September 30, 2020 includes the reversal of $4.8 million of cumulative previously recognized expense for the 2019 Grants, which were determined to be not probable of vesting, offset in part by related DERs for the 2019 Grants previously recorded to equity and then expensed.

The total obligation associated with LTIP grants of restricted units as of September 30, 2021 was $5.1 million and is included in the partners' capital Limited partners-common unitholders line item in our condensed consolidated balance sheets. As of September 30, 2021, there was $12.6 million in total unrecognized compensation expense related to the non-vested LTIP restricted unit grants that are expected to vest. That expense is expected to be recognized over a weighted-average period of 1.8 years.

Supplemental Executive Retirement Plan and Directors' Deferred Compensation Plan

We utilize the SERP to provide deferred compensation benefits for certain officers and key employees. All allocations made to participants under the SERP are made in the form of "phantom" ARLP units and SERP distributions will be settled in the form of ARLP common units. The SERP is administered by the Compensation Committee.

Our directors participate in the Directors' Deferred Compensation Plan. Pursuant to the Directors' Deferred Compensation Plan, for amounts deferred either automatically or at the election of the director, a notional account is established and credited with notional common units of ARLP, described in the Directors' Deferred Compensation Plan as "phantom" units. Distributions from the Directors' Deferred Compensation Plan will be settled in the form of ARLP common units.

For both the SERP and Directors' Deferred Compensation Plan, when quarterly cash distributions are made with respect to ARLP common units, an amount equal to such quarterly distribution is credited to each participant's notional account as additional phantom units. All grants of phantom units under the SERP and Directors' Deferred Compensation Plan vest immediately.

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A summary of SERP and Directors' Deferred Compensation Plan activity as of and for the nine months ended September 30, 2021 is as follows:


	Number of units	Weighted average grant date fair value per unit		Intrinsic value
				(in thousands)

Phantom units outstanding as of January 1, 2021	760,630	$	22.04	$	3,408
Granted	22,777		6.97
Issued (1)	(138,570)		25.86
Phantom units outstanding as of September 30, 2021	644,837		20.69		7,009

(1)	During the nine months ended September 30, 2021, we issued 102,962 ARLP common units purchased on the open market to a participant under the SERP. Units issued were net of units settled in cash to satisfy tax withholding obligations.

Total SERP and Directors' Deferred Compensation Plan expense was $0.1 million for the three months ended September 30, 2021 and 2020, and $0.3 million and $0.4 million for the nine months ended September 30, 2021, and 2020, respectively. As of September 30, 2021, the total obligation associated with the SERP and Directors' Deferred Compensation Plan was $13.3 million and is included in the partners' capital Limited partners-common unitholders line item in our condensed consolidated balance sheets.

15.COMPONENTS OF PENSION PLAN NET PERIODIC BENEFIT COSTS

Eligible employees at certain of our mining operations participate in a defined benefit plan (the "Pension Plan") that we sponsor. The Pension Plan is currently closed to new applicants and participants in the Pension Plan are no longer receiving benefit accruals for service. The benefit formula for the Pension Plan is a fixed dollar unit based on years of service. Components of the net periodic benefit cost for each of the periods presented are as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Interest cost	$	860	$	1,030	$	2,580	$	3,138
Expected return on plan assets		(1,671)		(1,413)		(5,013)		(4,396)
Amortization of prior service cost		47		47		140		140
Amortization of net loss		1,141		969		3,424		3,096
Net periodic benefit cost (1)	$	377	$	633	$	1,131	$	1,978

(1)

Net periodic benefit cost for the Pension Plan is included in the Other expense line item within our condensed consolidated statements of operations.

During the nine months ended September 30, 2021, we made contribution payments totaling $3.3 million to the Pension Plan for the 2020 plan year. As a result of certain pension plan contribution relief provided by the American Rescue Plan Act enacted in March 2021, we do not expect to make additional contributions to the Pension Plan during 2021 or 2022.

16.SEGMENT INFORMATION

We operate in the United States as a diversified natural resource company that generates operating and royalty income from the production and marketing of coal to major domestic and international utilities and industrial users as well as royalty income from oil & gas mineral interests. We aggregate multiple operating segments into four reportable segments, Illinois Basin Coal Operations, Appalachia Coal Operations, Oil & Gas Royalties and Coal Royalties. We also have an "all other" category referred to as Other, Corporate and Elimination.

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Our two coal operations reportable segments correspond to major coal producing regions in the eastern United States with similar economic characteristics including coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues. The two coal operations reportable segments include seven mining complexes operating in Illinois, Indiana, Kentucky, Maryland, Pennsylvania and West Virginia and a coal loading terminal in Indiana on the Ohio River. Our Oil & Gas Royalties reportable segment includes our oil & gas mineral interests which are located primarily in the Permian (Delaware and Midland), Anadarko (SCOOP/STACK), and Williston (Bakken) basins. The operations within our Oil & Gas Royalties reportable segment primarily include receiving royalties and lease bonuses for our oil & gas mineral interests. Our Coal Royalties reportable segment includes coal reserves controlled by Alliance Resource Properties, which are either (a) leased to certain of our coal mining entities or (b) unleased but near our coal mining operations.

Beginning in the first quarter of 2021, we began to strategically view and manage our coal royalty activities separately from our coal mining operations since acquiring and managing a variety of royalty producing assets have similar management attributes. As a result, we restructured our reportable segments to better reflect this strategic view in how we manage our business and allocate resources. Prior periods have been recast to include Alliance Resource Properties within our new Coal Royalties reportable segment with offsetting recast adjustments primarily to our coal operations reportable segments and to a lesser extent, our Other, Corporate and Elimination category. Eliminations reported in Other, Corporate and Elimination were also recast to reflect intercompany royalty revenues and offsetting intercompany royalty expense resulting from our new Coal Royalties reportable segment.

The Illinois Basin Coal Operations reportable segment includes currently operating mining complexes (a) the Gibson County Coal, LLC ("Gibson") mining complex, which includes the Gibson South mine, (b) the Warrior Coal, LLC ("Warrior") mining complex, (c) the River View Coal, LLC ("River View") mining complex and (d) the Hamilton mining complex. The Illinois Basin Coal Operations reportable segment also includes our currently operating Mt. Vernon Transfer Terminal, LLC ("Mt. Vernon") coal loading terminal in Indiana on the Ohio River. Our Coal Royalties reportable segment discussed below, controls other coal reserves near our Illinois Basin operations which have not yet been leased to our Illinois Basin mining entities.

The Illinois Basin Coal Operations reportable segment also includes Mid-America Carbonates, LLC ("MAC") and other support services as well as non-operating mining complexes including (a) the Gibson North mine, which ceased production in the fourth quarter of 2019, (b) Webster County Coal, LLC's Dotiki mining complex, (c) White County Coal, LLC's Pattiki mining complex, (d) Hopkins County Coal, LLC's mining complex, and (e) Sebree Mining, LLC's mining complex.

The Appalachia Coal Operations reportable segment includes currently operating mining complexes (a) the Mettiki mining complex, (b) the Tunnel Ridge, LLC mining complex ("Tunnel Ridge") and (c) the MC Mining, LLC mining complex. The Mettiki mining complex includes Mettiki Coal (WV), LLC's Mountain View mine and Mettiki Coal, LLC's preparation plant. Our Coal Royalties reportable segment discussed below, controls the Penn Ridge coal reserves near our Tunnel Ridge operations which have not yet been leased to Tunnel Ridge.

The Oil & Gas Royalties reportable segment includes oil & gas mineral interests held by AR Midland, LP and AllDale I & II and includes Alliance Minerals' equity interests in both AllDale III (Note 9 – Investment) and Cavalier Minerals.

The Coal Royalties reportable segment includes coal reserves controlled by Alliance Resource Properties, that are either (a) leased to certain of our mining complexes in both the Illinois Basin Coal Operations and Appalachia Coal Operations reportable segments or (b) near our coal mining operations but not yet leased to our coal mining entities. About two thirds of the coal sold by our Coal Operations' mines is leased from our Coal Royalties entities.

Other, Corporate and Elimination includes marketing and administrative activities, Matrix Design Group, LLC and its subsidiaries ("Matrix Design"), Alliance Design Group, LLC ("Alliance Design") (collectively, Matrix Design and Alliance Design referred to as the "Matrix Group"), Pontiki Coal, LLC's workers' compensation and pneumoconiosis liabilities, Wildcat Insurance, LLC ("Wildcat Insurance"), which assists the ARLP Partnership with its insurance requirements, AROP Funding and Alliance Finance (both discussed in Note 7 – Long-Term Debt) and other miscellaneous activities. The eliminations included in Other, Corporate and Elimination primarily represent the intercompany coal royalty transactions described above between our Coal Royalties reportable segment and our coal operations' mines.

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Reportable segment results are presented below.


	Coal Operations				Royalties				Other,
	Illinois								Corporate and
	Basin		Appalachia		Oil & Gas		Coal		Elimination		Consolidated

	(in thousands)
Three Months Ended September 30, 2021

Revenues - Outside	$	231,093	$	154,944	$	21,191	$	—	$	8,211	$	415,439
Revenues - Intercompany		—		—		—		13,456		(13,456)		—
Total revenues (1)		231,093		154,944		21,191		13,456		(5,245)		415,439

Segment Adjusted EBITDA Expense (2)		149,666		92,312		2,639		4,258		(9,525)		239,350
Segment Adjusted EBITDA (3)		69,305		52,726		19,080		9,198		4,280		154,589
Capital expenditures		19,081		12,531		—		30		1,393		33,035

Three Months Ended September 30, 2020

Revenues - Outside	$	210,319	$	132,310	$	9,721	$	42	$	3,259	$	355,651
Revenues - Intercompany		—		—		—		11,406		(11,406)		—
Total revenues (1)		210,319		132,310		9,721		11,448		(8,147)		355,651

Segment Adjusted EBITDA Expense (2)		131,014		86,701		849		5,161		(6,975)		216,750
Segment Adjusted EBITDA (3)		75,583		43,105		8,898		6,287		(1,172)		132,701
Capital expenditures		3,815		14,541		—		—		219		18,575

Nine Months Ended September 30, 2021

Revenues - Outside	$	640,260	$	384,286	$	52,798	$	—	$	19,160	$	1,096,504
Revenues - Intercompany		—		—		—		36,410		(36,410)		—
Total revenues (1)		640,260		384,286		52,798		36,410		(17,250)		1,096,504

Segment Adjusted EBITDA Expense (2)		415,423		240,494		7,116		13,157		(24,619)		651,571
Segment Adjusted EBITDA (3)		197,601		125,873		46,405		23,253		7,370		400,502
Total assets		703,060		422,504		601,695		289,100		132,616		2,148,975
Capital expenditures		47,997		34,579		—		30		6,055		88,661

Nine Months Ended September 30, 2020

Revenues - Outside	$	551,978	$	367,523	$	31,831	$	47	$	10,237	$	961,616
Revenues - Intercompany		—		—		—		29,555		(29,555)		—
Total revenues (1)		551,978		367,523		31,831		29,602		(19,318)		961,616

Segment Adjusted EBITDA Expense (2)		399,664		240,846		2,851		12,649		(17,021)		638,989
Segment Adjusted EBITDA (3)		141,583		120,686		29,534		16,953		(2,298)		306,458
Total assets		799,936		461,751		616,491		291,854		61,308		2,231,340
Capital expenditures		44,073		57,798		—		—		949		102,820

(1)	Revenues included in the Other, Corporate and Elimination column are attributable to intercompany eliminations, which are primarily the coal royalties intercompany eliminations, outside revenues at the Matrix Group and other outside miscellaneous sales and revenue activities.

(2)	Segment Adjusted EBITDA Expense includes operating expenses, coal purchases and other income. Transportation expenses are excluded as transportation revenues are recognized in an amount equal to transportation expenses when title passes to the customer.

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The following is a reconciliation of consolidated Segment Adjusted EBITDA Expense to Operating expenses (excluding depreciation, depletion and amortization):


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Segment Adjusted EBITDA Expense	$	239,350	$	216,750	$	651,571	$	638,989
Outside coal purchases		(6,065)		—		(6,179)		—
Other expense		(84)		(723)		(2,632)		(1,456)
Operating expenses (excluding depreciation, depletion and amortization)	$	233,201	$	216,027	$	642,760	$	637,533

(3)

Segment Adjusted EBITDA is defined as net income (loss) attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization, general and administrative expenses and asset and goodwill impairments. Management therefore is able to focus solely on the evaluation of segment operating profitability as it relates to our revenues and operating expenses, which are primarily controlled by our segments. Consolidated Segment Adjusted EBITDA is reconciled to net income as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Consolidated Segment Adjusted EBITDA	$	154,589	$	132,701	$	400,502	$	306,458
General and administrative		(18,655)		(13,871)		(51,651)		(41,131)
Depreciation, depletion and amortization		(68,763)		(80,182)		(192,698)		(237,662)
Asset impairments		—		—		—		(24,977)
Goodwill impairment		—		—		—		(132,026)
Interest expense, net		(9,389)		(11,156)		(29,595)		(34,799)
Income tax expense		(234)		(293)		(227)		(111)
Net income (loss) attributable to ARLP	$	57,548	$	27,199	$	126,331	$	(164,248)
Noncontrolling interest		176		36		384		97
Net income (loss)	$	57,724	$	27,235	$	126,715	$	(164,151)

17.SUBSEQUENT EVENTS

Other than the events described below and in Note 10, there were no subsequent events.

On October 13, 2021, ARLP acquired approximately 1,480 oil & gas net royalty acres in the Delaware Basin from Boulders Royalty Corp. for a purchase price of $31.0 million, which was funded with cash on hand. This acquisition enhances our ownership position in the Permian Basin and furthers our business strategy to grow our Oil & Gas Royalties segment.

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ITEM 2.MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Significant relationships referenced in this management's discussion and analysis of financial condition and results of operations include the following:

●

References to "we," "us," "our" or "ARLP Partnership" mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.

●

References to "ARLP" mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.

●

References to "MGP" mean Alliance Resource Management GP, LLC, ARLP's general partner.

●

References to "Mr. Craft" mean Joseph W. Craft III, the Chairman, President and Chief Executive Officer of MGP.

●

References to "Intermediate Partnership" mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P.

●

References to "Alliance Coal" mean Alliance Coal, LLC, the holding company for our coal mining operations.

●

References to "Alliance Minerals" mean Alliance Minerals, LLC, the holding company for our oil and gas minerals interests.

●

Summary

We are a diversified natural resource company operating in the United States that generates operating and royalty income from the production and marketing of coal to major domestic and international utilities and industrial users as well as royalty income from oil & gas mineral interests. We began coal mining operations in 1971 and, since then, have grown through acquisitions and internal development in strategic producing regions to become the second largest coal producer in the eastern United States. Our mining operations are located near many of the major eastern utility generating plants and on major coal hauling railroads in the eastern United States. Two of our mines are located on the banks of the Ohio River. As is customary in the coal industry, we have entered into long-term coal supply agreements with many of our customers. In addition to our mining operations, in 2007, Alliance Resource Properties began acquiring control of coal mineral interests and leasing the coal reserves to our mining operations. In 2014, we began acquiring oil & gas mineral interests in premier oil & gas producing regions across the United States.

We have four reportable segments, Illinois Basin Coal Operations, Appalachia Coal Operations, Oil & Gas Royalties and Coal Royalties. We also have an "all other" category referred to as Other, Corporate and Elimination. Our two coal operations reportable segments correspond to major coal producing regions in the eastern United States with similar economic characteristics including coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues. The two coal operations reportable segments include seven mining complexes operating in Illinois, Indiana, Kentucky, Maryland, Pennsylvania and West Virginia and a coal loading terminal in Indiana on the Ohio River. Our Oil & Gas Royalties reportable segment includes our oil & gas mineral interests which are located primarily in the Permian (Delaware and Midland), Anadarko (SCOOP/STACK), and Williston (Bakken) basins. Our ownership in these basins includes approximately 55,500 net royalty acres which provides us with diversified exposure to industry leading operators consistent with our general business strategy to grow our oil & gas mineral interest business. We market our oil & gas mineral interests for lease to operators in those regions and generate royalty income from the leasing and development of those mineral interests. Our Coal Royalties reportable segment includes coal reserves controlled by Alliance Resource Properties, which are either (a) leased to certain of our coal mining entities or (b) unleased but near our coal mining operations.

Beginning in the first quarter of 2021, we began to strategically view and manage our coal royalty activities separately from our coal operations since acquiring and managing a variety of royalty producing assets have similar management attributes. As a result, we restructured our reportable segments to better reflect this strategic view in how we manage our business and allocate resources. Prior periods have been recast to include Alliance Resource Properties within our new Coal Royalties reportable segment with offsetting recast adjustments primarily to our coal operations reportable segments and to a lesser extent, our Other, Corporate and Elimination category. Eliminations reported in Other, Corporate

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and Elimination were also recast to reflect intercompany royalty revenues and offsetting intercompany royalty expense resulting from our new Coal Royalties reportable segment.

●

Illinois Basin Coal Operations reportable segment includes currently operating mining complexes (a) the Gibson County Coal, LLC ("Gibson") mining complex, which includes the Gibson South mine, (b) the Warrior Coal, LLC ("Warrior") mining complex, (c) the River View Coal, LLC ("River View") mining complex and (d) the Hamilton County Coal, LLC ("Hamilton") mining complex. The Illinois Basin Coal Operations reportable segment also includes our operating Mt. Vernon Transfer Terminal, LLC ("Mt. Vernon") coal loading terminal in Indiana on the Ohio River. Our Coal Royalties reportable segment controls other coal reserves near our Illinois Basin operations, which have not yet been leased to our Illinois Basin mining entities.

The Illinois Basin Coal Operations reportable segment also includes Mid-America Carbonates, LLC ("MAC") and other support services as well as non-operating mining complexes (a) the Gibson North mine, which ceased production in fourth quarter of 2019, (b) Webster County Coal, LLC's Dotiki mining complex, (c) White County Coal, LLC's Pattiki mining complex, (d) Hopkins County Coal, LLC's mining complex, and (e) Sebree Mining, LLC's mining complex.

●

Appalachia Coal Operations reportable segment includes currently operating mining complexes (a) the Mettiki mining complex, (b) the Tunnel Ridge, LLC mining complex ("Tunnel Ridge"), and (c) the MC Mining, LLC mining complex ("MC Mining"). The Mettiki mining complex includes Mettiki Coal (WV), LLC's Mountain View mine and Mettiki Coal, LLC's preparation plant. Our Coal Royalties reportable segment discussed below, controls the Penn Ridge coal reserves near our Tunnel Ridge operations which have not yet been leased to Tunnel Ridge.

●

Oil & Gas Royalties reportable segment includes oil & gas mineral interests held by AR Midland, LP ("AR Midland") and AllDale I & II and includes Alliance Minerals' equity interests in both AllDale Minerals III, LP ("AllDale III") (Note 9 – Investment) and Cavalier Minerals. Please read "Item 1. Financial Statements (Unaudited)—Note 9 – Investment" of this Quarterly Report on Form 10-Q for more information on AllDale III.

●

Coal Royalties reportable segment includes coal reserves held or controlled by Alliance Resource Properties, consisting of (a) reserves leased to certain of our mining complexes in both the Illinois Basin Coal Operations and Appalachia Coal Operations reportable segments and (b) reserves near our coal mining operations but not yet leased to our coal mining entities. About two thirds of the coal sold by our Coal Operations' mines is leased from our Coal Royalties entities.

●

Other, Corporate and Elimination includes marketing and administrative activities, Matrix Design Group, LLC and its subsidiaries ("Matrix Design"), Alliance Design Group, LLC ("Alliance Design") (collectively, Matrix Design and Alliance Design referred to as the "Matrix Group"), Pontiki Coal, LLC's workers' compensation and pneumoconiosis liabilities, Wildcat Insurance, LLC ("Wildcat Insurance"), which assists the ARLP Partnership with its insurance requirements, AROP Funding and Alliance Finance (both discussed in Note 7 – Long-Term Debt) and other miscellaneous activities. The eliminations included in Other, Corporate and Elimination primarily represent the intercompany coal royalty transactions described above between our Coal Royalties reportable segment and our coal operations' mines. Please read "Item 1. Financial Statements (Unaudited)—Note 7 – Long-Term Debt" of this Quarterly Report on Form 10-Q for more information on AROP Funding.

Three Months Ended September 30, 2021 Compared to Three Months Ended September 30, 2020

We reported net income attributable to ARLP of $57.5 million for the three months ended September 30, 2021 ("2021 Quarter") compared to $27.2 million for the three months ended September 30, 2020 ("2020 Quarter"). The increase of $30.3 million was primarily due to higher revenues, partially offset by increased total operating expenses. Total revenues in the 2021 Quarter increased by 16.8% to $415.4 million compared to $355.7 million in the 2020 Quarter as a result of higher coal sales volumes and significantly higher oil & gas prices. In general, results from coal operations and oil & gas royalties for the 2021 Quarter were significantly improved compared to the 2020 Quarter, which was negatively impacted by the COVID-19 pandemic.

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	Three Months Ended September 30,
	2021		2020		2021		2020

	(in thousands)				(per ton / per BOE sold)

Coal - Tons sold		8,494		7,702		N/A		N/A
Coal - Tons produced		7,986		7,202		N/A		N/A
Coal - Coal sales	$	362,264	$	335,767	$	42.65	$	43.59
Coal - Segment Adjusted EBITDA Expense (1) (2)	$	245,909	$	222,146	$	28.95	$	28.84
Oil & Gas Royalties - BOE sold		414		468		N/A		N/A
Oil & Gas Royalties - Royalties (3)	$	20,109	$	9,693	$	48.64	$	20.71
Coal Royalties - Tons sold		5,344		5,098		N/A		N/A
Coal Royalties - Intercompany royalties	$	13,456	$	11,406	$	2.52	$	2.24

(1)	For a definition of Segment Adjusted EBITDA Expense and related reconciliation to comparable generally accepted accounting principles ("GAAP") financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses."

(2)	Coal - Segment Adjusted EBITDA Expense is defined as consolidated Segment Adjusted EBITDA Expense excluding expenses of our Oil & Gas Royalties segment and is adjusted for intercompany transactions with our Coal Royalties segment.

(3)	Average sales price per BOE is defined as oil & gas royalty revenues excluding lease bonus revenue divided by total BOE sold.

Coal sales. Coal sales increased $26.5 million or 7.9% to $362.3 million for the 2021 Quarter from $335.8 million for the 2020 Quarter. The increase was attributable to a volume variance of $34.5 million resulting from increased tons sold, partially offset by a price variance of $8.0 million due to lower average coal sales prices. Improved coal demand primarily in the export markets during the 2021 Quarter drove coal sales volumes higher by 10.3% to 8.5 million tons sold compared to 7.7 million tons sold in the 2020 Quarter, which was adversely impacted by the pandemic. Coal sales price realizations decreased by 2.2% in the 2021 Quarter to $42.65 per ton sold, compared to $43.59 per ton sold during the 2020 Quarter, due to the expiration of higher priced contract shipments.

Coal - Segment Adjusted EBITDA Expense. Segment Adjusted EBITDA Expense for our coal operations increased 10.7% to $245.9 million, as a result of higher coal sales volumes. On a per ton basis, Segment Adjusted EBITDA Expense for our coal operations increased slightly in the 2021 Quarter to $28.95 per ton sold, compared to $28.84 per ton in the 2020 Quarter, primarily due to certain cost increases, which are discussed below by category:

●

Material and supplies expenses per ton produced increased 8.4% to $10.38 per ton in the 2021 Quarter from $9.58 per ton in the 2020 Quarter. The increase of $0.80 per ton produced primarily reflects increases of $0.78 per ton for roof support, $0.33 per ton for contract labor used in the mining process and $0.24 per ton for power and fuel used in the mining process, partially offset by a decrease of $0.43 per ton in longwall subsidence expense.

●

Outside coal purchases increased $6.1 million in the 2021 Quarter as a result of sales from purchased coal, which generally costs higher on a per ton basis than our produced coal.

Segment Adjusted EBITDA Expense increases per ton were partially offset by the following decreases:

●

Labor and benefit expenses per ton produced, excluding workers' compensation, decreased 11.5% to $9.19 per ton in the 2021 Quarter from $10.39 per ton in the 2020 Quarter. The decrease of $1.20 per ton was primarily due to a) increased volumes which in turn lowered certain fixed costs per ton, b) reduced benefit accruals and c) favorable medical adjustments.

●

Workers' compensation expenses per ton produced decreased to $(0.07) per ton in the 2021 Quarter from $0.45 per ton in the 2020 Quarter. The decrease of $0.52 per ton produced resulted primarily from refunds received in the 2021 Quarter on assessments paid to the state of Kentucky in prior years.

Oil & gas royalties. Oil & gas royalty revenues increased to $20.1 million in the 2021 Quarter compared to $9.7 million for the 2020 Quarter. The increase of $10.4 million was primarily due to significantly higher sales price realizations per BOE discussed above.

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Other revenues. Other revenues were principally comprised of Matrix Design sales and other miscellaneous sales and revenue activities. Other revenues increased to $11.0 million in the 2021 Quarter from $4.0 million in the 2020 Quarter. The increase of $7.0 million was primarily due to increased sales of mining technology products by our Matrix Design subsidiary and other smaller variances in the 2021 Quarter.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense decreased to $68.8 million for the 2021 Quarter compared to $80.2 million for the 2020 Quarter primarily as a result of increased mine life estimates for certain mines and reduced depreciation associated with coal inventory changes.

Transportation revenues and expenses. Transportation revenues and expenses were $22.0 million and $6.2 million for the 2021 and 2020 Quarters, respectively. The increase of $15.8 million was primarily attributable to increased average third-party transportation rates in the 2021 Quarter and increased coal shipments to international markets for which we arrange third-party transportation. Transportation revenues are recognized when title to the coal passes to the customer and recognized in an amount equal to the corresponding transportation expenses.

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Segment Adjusted EBITDA. Our 2021 Quarter Segment Adjusted EBITDA increased $21.9 million to $154.6 million from the 2020 Quarter Segment Adjusted EBITDA of $132.7 million. Segment Adjusted EBITDA, tons sold, coal sales, other revenues, Segment Adjusted EBITDA Expense, oil & gas royalties, BOE volume, coal royalties and coal royalties tons sold by segment are as follows:


	Three Months Ended
	September 30,
	2021		2020		Increase (Decrease)

	(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations	$	69,305	$	75,583	$	(6,278)	(8.3)	%
Appalachia Coal Operations		52,726		43,105		9,621	22.3	%
Oil & Gas Royalties		19,080		8,898		10,182	114.4	%
Coal Royalties		9,198		6,287		2,911	46.3	%
Other, Corporate and Elimination (2)		4,280		(1,172)		5,452	(1)
Total Segment Adjusted EBITDA (3)	$	154,589	$	132,701	$	21,888	16.5	%

Coal - Tons sold
Illinois Basin Coal Operations		5,750		5,219		531	10.2	%
Appalachia Coal Operations		2,744		2,483		261	10.5	%
Total tons sold		8,494		7,702		792	10.3	%

Coal sales
Illinois Basin Coal Operations	$	217,637	$	206,356	$	11,281	5.5	%
Appalachia Coal Operations		144,627		129,411		15,216	11.8	%
Total coal sales	$	362,264	$	335,767	$	26,497	7.9	%

Other revenues
Illinois Basin Coal Operations	$	1,335	$	241	$	1,094	(1)
Appalachia Coal Operations		411		395		16	4.1	%
Oil & Gas Royalties		1,082		28		1,054	(1)
Coal Royalties		—		42		(42)	(100.0)	%
Other, Corporate and Elimination		8,211		3,259		4,952	151.9	%
Total other revenues	$	11,039	$	3,965	$	7,074	178.4	%

Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations	$	149,666	$	131,014	$	18,652	14.2	%
Appalachia Coal Operations		92,312		86,701		5,611	6.5	%
Oil & Gas Royalties		2,639		849		1,790	210.8	%
Coal Royalties		4,258		5,161		(903)	(17.5)	%
Other, Corporate and Elimination (2)		(9,525)		(6,975)		(2,550)	(36.6)	%
Total Segment Adjusted EBITDA Expense	$	239,350	$	216,750	$	22,600	10.4	%

Oil & Gas Royalties
Volume - BOE (4)		414		468		(54)	(11.5)	%
Oil & gas royalties	$	20,109	$	9,693	$	10,416	107.5	%

Coal Royalties
Volume - Tons sold (5)		5,344		5,098		246	4.8	%
Intercompany coal royalties	$	13,456	$	11,406	$	2,050	18.0	%

(1)	Percentage change not meaningful.

(2)	Other, Corporate and Elimination includes the elimination of intercompany coal royalty revenues and expenses between our Coal Royalties Segment and our Coal Operations Segments in addition to the expenses for the other miscellaneous activities included in this category.

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(3)	For a definition of Segment Adjusted EBITDA and related reconciliation to comparable GAAP financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income (loss)."

(4)	Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel).

(5)	Represents tons sold by our Coal Operations Segments associated with coal reserves leased from our Coal Royalties Segment.

Illinois Basin Coal Operations – Segment Adjusted EBITDA decreased to $69.3 million in the 2021 Quarter from $75.6 million in the 2020 Quarter. The decrease of $6.3 million was primarily attributable to lower coal sales price realizations and higher expenses per ton, partially offset by increased coal sales volumes. Coal sales increased 5.5% to $217.6 million in the 2021 Quarter from $206.4 million in the 2020 Quarter resulting from higher sales volumes, which increased 10.2% due to improved coal demand primarily in the export markets. Coal sales price per ton sold in the 2021 Quarter decreased by 4.3% compared to the 2020 Quarter reflecting the expiration of higher-priced sales contracts and a greater mix of lower-priced export sales volumes. Segment Adjusted EBITDA Expense increased 14.2% to $149.7 million in the 2021 Quarter from $131.0 million in the 2020 Quarter primarily as a result of increased sales volumes and higher expenses per ton. Segment Adjusted EBITDA Expense per ton increased $0.93 per ton sold to $26.03 from $25.10 per ton sold in the 2020 Quarter primarily as a result of increased roof support and maintenance expenses as well as higher labor costs per ton across the region. These increases were partially offset by reduced benefit accruals and workers compensation refunds received in the 2021 Quarter.

Appalachia Coal Operations – Segment Adjusted EBITDA increased 22.3% to $52.7 million for the 2021 Quarter from $43.1 million in the 2020 Quarter. The increase of $9.6 million was primarily attributable to higher coal sales, which increased 11.8% to $144.6 million in the 2021 Quarter from $129.4 million in the 2020 Quarter. The increase in coal sales reflects higher tons sold, which rose 10.5% in the 2021 Quarter compared to the 2020 Quarter due to increased sales volumes at our Tunnel Ridge and MC Mining operations resulting from improved market conditions. Segment Adjusted EBITDA Expense increased 6.5% to $92.3 million in the 2021 Quarter from $86.7 million in the 2020 Quarter due to increased sales volumes, partially offset by lower expenses per ton. Segment Adjusted EBITDA Expense per ton decreased $1.28 per ton sold to $33.64 compared to $34.92 per ton sold in the 2020 Quarter, as a result of increased volumes and reduced longwall subsidence expense in the 2021 Quarter and a longwall move in the 2020 Quarter at our Tunnel Ridge mine, the production benefits from MC Mining’s transition of mining operations to a new reserve area in the second half of 2020 and the benefits of ongoing expense control and efficiency initiatives. In addition, see certain cost variances described above under "–Coal - Segment Adjusted EBITDA Expense."

Oil & Gas Royalties – Segment Adjusted EBITDA increased to $19.1 million for the 2021 Quarter from $8.9 million in the 2020 Quarter. The increase of $10.2 million was primarily due to significantly higher sales price realizations per BOE in the 2021 Quarter compared to the 2020 Quarter, which more than offset lower volumes and higher Segment Adjusted EBITDA Expense.

Coal Royalties – Segment Adjusted EBITDA increased 46.3% to $9.2 million for the 2021 Quarter from $6.3 million in the 2020 Quarter. The increase of $2.9 million was a result of increased royalty tons sold and higher average royalty rates per ton.

Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

We reported net income attributable to ARLP of $126.3 million for the nine months ended September 30, 2021 ("2021 Period") compared to a net loss attributable to ARLP of $164.2 million for the nine months ended September 30, 2020 ("2020 Period"). The increase of $290.5 million resulted from higher revenues and lower depreciation in the 2021 Period and $157.0 million of non-cash impairment charges in the 2020 Period. Increased coal sales volumes and oil & gas prices in the 2021 Period drove total revenues higher by 14.0% to $1.10 billion, compared to $961.6 million for the 2020 Period. In general, results from coal operations and oil & gas royalties for the 2021 Period were significantly improved compared to the 2020 Period, which was impacted by reduced global energy demand and weak commodity prices as a result of lockdown measures imposed in response to the COVID-19 pandemic.

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	Nine Months Ended September 30,
	2021		2020		2021		2020

	(in thousands)				(per ton / per BOE sold)
Coal - Tons sold		23,168		20,139		N/A		N/A
Coal - Tons produced		23,468		19,546		N/A		N/A
Coal - Coal sales	$	975,725	$	886,690	$	42.12	$	44.03
Coal - Segment Adjusted EBITDA Expense (1) (2)	$	667,708	$	653,044	$	28.82	$	32.43
Oil & Gas Royalties - BOE sold		1,205		1,374		N/A		N/A
Oil & Gas Royalties - Royalties (3)	$	51,222	$	31,718	$	42.52	$	23.08
Coal Royalties - Tons sold		14,572		13,537		N/A		N/A
Coal Royalties - Intercompany royalties	$	36,410	$	29,555	$	2.50	$	2.18

(1)	For a definition of Segment Adjusted EBITDA Expense and related reconciliation to comparable generally accepted accounting principles ("GAAP") financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses."

(2)	Coal - Segment Adjusted EBITDA Expense is defined as consolidated Segment Adjusted EBITDA Expense excluding expenses of our Oil & Gas Royalties segment and is adjusted for intercompany transactions with our Coal Royalties segment.

(3)	Average sales price per BOE is defined as oil & gas royalty revenues excluding lease bonus revenue divided by total BOE sold.

Coal sales. Coal sales increased $89.0 million or 10.0% to $975.7 million for the 2021 Period from $886.7 million for the 2020 Period. The increase was attributable to a volume variance of $133.4 million resulting from increased tons sold partially offset by a negative price variance of $44.4 million due to lower average coal sales prices. Tons sold increased 15.0% to 23.2 million tons in the 2021 Period due to improved coal demand and increased export shipments. Primarily due to the expiration of higher priced contract shipments, coal sales price realizations declined 4.3% in the 2021 Period to $42.12 per ton sold, compared to $44.03 per ton sold during the 2020 Period. Production volumes increased by 20.1% in the 2021 Period, reflecting the temporary idling and scaling back of production at certain mines during the 2020 Period in response to weak market conditions resulting from the pandemic.

Coal - Segment Adjusted EBITDA Expense. Segment Adjusted EBITDA Expense for our coal operations was comparable to the 2020 Period as increased expenses resulting from higher sales volumes in the 2021 Period were primarily offset by reduced per ton costs in the 2021 Period. Segment Adjusted EBITDA Expense per ton decreased 11.1% in the 2021 Period to $28.82 per ton, compared to $32.43 per ton in the 2020 Period. The decrease was attributed primarily to increased volumes lowering fixed costs per ton, lower inventory charges, improved recoveries at several mines and the impact of ongoing expense control and efficiency initiatives at all of our mining operations in addition to other cost decreases which are discussed below by category:

●

Labor and benefit expenses per ton produced, excluding workers' compensation, decreased 15.4% to $9.32 per ton in the 2021 Period from $11.02 per ton in the 2020 Period. The decrease of $1.70 per ton was primarily due to increased volumes at our Illinois Basin mines where production was temporarily idled in the 2020 Period in response to weak market conditions resulting from the pandemic.

●

Workers' compensation expenses per ton produced decreased to $0.18 per ton in the 2021 Period from $0.63 per ton in the 2020 Period. The decrease of $0.45 per ton produced resulted from refunds received in the 2021 Period on assessments paid to the state of Kentucky in prior years and favorable mid-year workers' compensation accrual adjustments in the 2021 Period, primarily due to an increase in the discount rate, compared to the 2020 Period, which had a valuation loss due to unfavorable changes in claims development and a decrease in the discount rate.

●

Material and supplies expenses per ton produced decreased 6.5% to $9.85 per ton in the 2021 Period from $10.53 per ton in the 2020 Period. The decrease of $0.68 per ton produced primarily reflects decreases of $0.47 per ton for outside expenses used in the mining processes, $0.25 per ton for environmental and reclamation expenses other than longwall subsidence and $0.19 per ton for power and fuel used in the mining process, partially offset by an increase of $0.51 per ton for roof support.

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●

Maintenance expenses per ton produced decreased 17.0% to $2.68 per ton in the 2021 Period from $3.23 per ton in the 2020 Period. The decrease of $0.55 per ton produced was primarily due to increased production and improved recoveries previously mentioned.

Oil & gas royalties. Oil & gas royalty revenues increased to $51.2 million in the 2021 Period compared to $31.7 million for the 2020 Period. The increase of $19.5 million was primarily due to significantly higher sales price realizations per BOE.

Other revenues. Other revenues were principally comprised of Matrix Design sales and other miscellaneous sales and revenue activities. Other revenues decreased to $24.4 million in the 2021 Period from $26.5 million in the 2020 Period. The decrease of $2.1 million was primarily due to a customer buy-out of certain coal contracts at our Tunnel Ridge mine during the 2020 Period, partially offset by increased sales of mining technology products by our Matrix Design subsidiary in the 2021 Period.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense decreased to $192.7 million for the 2021 Period compared to $237.7 million for the 2020 Period primarily as a result of increased mine life estimates for certain mines and reduced depreciation associated with a) coal inventory changes, b) certain mines closed prior to 2021 and c) lower BOE volumes.

Asset impairment. During the 2020 Period, we recorded $25.0 million of non-cash asset impairment charges due to sealing our idled Gibson North mine, resulting in its permanent closure, and a decrease in the fair value of certain mining equipment and greenfield coal reserves as a result of weakened coal market conditions. Please read "Item 1. Financial Statements (Unaudited)—Note 2 – Long-Lived Asset Impairments" of this Quarterly Report on Form 10-Q.

Goodwill impairment. During the 2020 Period, we recorded a $132.0 million non-cash goodwill impairment charge associated with our Hamilton mine, primarily as the result of reduced expected production volumes due to weakened coal market conditions and low energy demand resulting in part from the COVID-19 pandemic. Please read "Item 1. Financial Statements (Unaudited)—Note 3 – Goodwill Impairment " of this Quarterly Report on Form 10-Q.

Transportation revenues and expenses. Transportation revenues and expenses were $45.2 million and $16.7 million for the 2021 and 2020 Periods, respectively. The increase of $28.5 million was primarily attributable to increased average third-party transportation rates in the 2021 Period and increased coal shipments to international markets for which we arrange third-party transportation. Transportation revenues are recognized when title to the coal passes to the customer and recognized in an amount equal to the corresponding transportation expenses.

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Segment Adjusted EBITDA. Our 2021 Period Segment Adjusted EBITDA increased $94.0 million, or 30.7%, to $400.5 million from the 2020 Period Segment Adjusted EBITDA of $306.5 million. Segment Adjusted EBITDA, tons sold, coal sales, other revenues, Segment Adjusted EBITDA Expense, oil & gas royalties, BOE volume, coal royalties and coal royalties tons sold by segment are as follows:


	Nine Months Ended
	September 30,
	2021		2020		Increase (Decrease)

	(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations	$	197,601	$	141,583	$	56,018	39.6	%
Appalachia Coal Operations		125,873		120,686		5,187	4.3	%
Oil & Gas Royalties		46,405		29,534		16,871	57.1	%
Coal Royalties		23,253		16,953		6,300	37.2	%
Other, Corporate and Elimination (2)		7,370		(2,298)		9,668	(1)
Total Segment Adjusted EBITDA (3)	$	400,502	$	306,458	$	94,044	30.7	%

Coal - Tons sold
Illinois Basin Coal Operations		15,935		13,625		2,310	17.0	%
Appalachia Coal Operations		7,233		6,514		719	11.0	%
Total tons sold		23,168		20,139		3,029	15.0	%

Coal sales
Illinois Basin Coal Operations	$	610,435	$	539,614	$	70,821	13.1	%
Appalachia Coal Operations		365,290		347,076		18,214	5.2	%
Total coal sales	$	975,725	$	886,690	$	89,035	10.0	%

Other revenues
Illinois Basin Coal Operations	$	2,590	$	1,633	$	957	58.6	%
Appalachia Coal Operations		1,078		14,456		(13,378)	(92.5)	%
Oil & Gas Royalties		1,576		113		1,463	(1)
Coal Royalties		—		47		(47)	(100.0)	%
Other, Corporate and Elimination		19,160		10,237		8,923	87.2	%
Total other revenues	$	24,404	$	26,486	$	(2,082)	(7.9)	%

Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations	$	415,423	$	399,664	$	15,759	3.9	%
Appalachia Coal Operations		240,494		240,846		(352)	(0.1)	%
Oil & Gas Royalties		7,116		2,851		4,265	149.6	%
Coal Royalties		13,157		12,649		508	4.0	%
Other, Corporate and Elimination (2)		(24,619)		(17,021)		(7,598)	(44.6)	%
Total Segment Adjusted EBITDA Expense	$	651,571	$	638,989	$	12,582	2.0	%

Oil & Gas Royalties
Volume - BOE (4)		1,205		1,374		(169)	(12.3)	%
Oil & gas royalties	$	51,222	$	31,718	$	19,504	61.5	%

Coal Royalties
Volume - Tons sold (5)		14,572		13,537		1,035	7.6	%
Intercompany coal royalties	$	36,410	$	29,555	$	6,855	23.2	%

(1)	Percentage change not meaningful.

(2)	Other, Corporate and Elimination includes the elimination of intercompany coal royalty revenues and expenses between our Coal Royalties Segment and our Coal Operations Segments in addition to the expenses for the other miscellaneous activities included in this category.

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(3)	For a definition of Segment Adjusted EBITDA and related reconciliation to comparable GAAP financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income (loss)."

(4)	Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel).

(5)	Represents tons sold by our Coal Operations Segments associated with coal reserves leased from our Coal Royalties Segment.

Illinois Basin Coal Operations – Segment Adjusted EBITDA increased 39.6% to $197.6 million in the 2021 Period from $141.6 million in the 2020 Period. The increase of $56.0 million was primarily attributable to higher coal sales, which increased 13.1% to $610.4 million in the 2021 Period from $539.6 million in the 2020 Period. The increase of $70.8 million in coal sales primarily reflects increased sales volumes, which rose 17.0% compared to the 2020 Period due to improved coal demand and increased export volumes reflecting the continued economic recovery from the COVID-19 pandemic. Increased expenses resulting from higher coal sales volumes, partially offset by ongoing cost control and efficiency initiatives, contributed to higher Segment Adjusted EBITDA Expense of $415.4 million in the 2021 Period compared to $399.7 million in the 2020 Period. Segment Adjusted EBITDA Expense per ton decreased 11.1% to $26.07 from $29.33 per ton sold in the 2020 Period primarily as a result of increased volumes where production was temporarily idled and scaled back in the 2020 Period in response to weak market conditions resulting from the pandemic. Lower inventory charges and the impact of ongoing expense control and efficiency initiatives at all of our mining operations in the region also contributed to the decrease. In addition, also see certain cost variances described above under "–Coal - Segment Adjusted EBITDA Expense."

Appalachia Coal Operations – Segment Adjusted EBITDA increased 4.3% to $125.9 million for the 2021 Period from $120.7 million in the 2020 Period. The increase of $5.2 million was primarily attributable to higher coal sales, partially offset by a customer buy-out of certain coal contracts at our Tunnel Ridge mine during the 2020 Period. Coal sales increased 5.2% to $365.3 million in the 2021 Period compared to $347.1 million in the 2020 Period as a result of increased sales volumes, partially offset by lower price realizations. Tons sold increased 11.0% in the 2021 Period compared to the 2020 Period due to increased sales volumes at our Tunnel Ridge and MC Mining operations resulting from improved market conditions. Coal sales price per ton sold in the 2021 Period decreased 5.2% compared to the 2020 Period primarily due to the expiration of higher priced contract shipments. Segment Adjusted EBITDA Expense decreased slightly in the 2021 Period compared to the 2020 Period due to decreased per ton costs, partially offset by increased coal sales volumes. Segment Adjusted EBITDA Expense per ton decreased 10.1% to $33.25 compared to $36.97 per ton sold in the 2020 Period, as a result of increased sales volumes lowering fixed costs per ton, the full-year production benefit from MC Mining’s transition of mining operations to a new reserve area in the second half of 2020, ongoing expense control and efficiency initiatives and improved recoveries across the region. See also certain cost variances described above under "–Coal - Segment Adjusted EBITDA Expense."

Oil & Gas Royalties – Segment Adjusted EBITDA increased 57.1% to $46.4 million for the 2021 Period from $29.5 million in the 2020 Period. The increase of $16.9 million was primarily due to significantly higher sales price realizations per BOE, which more than offset lower volumes.

Coal Royalties – Segment Adjusted EBITDA increased 37.2% to $23.3 million for the 2021 Period from $17.0 million in the 2020 Period. The increase of $6.3 million was a result of increased royalty tons sold and higher average royalty rates per ton received from our mining subsidiaries.

Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income (loss)" and reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses"

Segment Adjusted EBITDA (a non-GAAP financial measure) is defined as net income (loss) attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization, general and administrative expenses and asset and goodwill impairments. Segment Adjusted EBITDA is a key component of consolidated EBITDA, which is used as a supplemental financial measure by management and by external users of our financial statements such as investors, commercial banks, research analysts and others. We believe that the presentation of EBITDA provides useful information to investors regarding our performance and results of operations because EBITDA, when used in conjunction with related GAAP financial measures, (i) provides additional information about our core operating performance and ability to generate and distribute cash flow, (ii) provides investors with the financial analytical framework upon which we base financial, operational, compensation and planning decisions and (iii) presents a measurement that investors, rating agencies and debt holders have indicated is useful in assessing us and our results of operations.

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Segment Adjusted EBITDA is also used as a supplemental financial measure by our management for reasons similar to those stated in the previous explanation of EBITDA. In addition, the exclusion of corporate general and administrative expenses from consolidated Segment Adjusted EBITDA allows management to focus solely on the evaluation of segment operating profitability as it relates to our revenues and operating expenses, which are primarily controlled by our segments.

The following is a reconciliation of consolidated Segment Adjusted EBITDA to net income (loss), the most comparable GAAP financial measure:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Consolidated Segment Adjusted EBITDA	$	154,589	$	132,701	$	400,502	$	306,458
General and administrative		(18,655)		(13,871)		(51,651)		(41,131)
Depreciation, depletion and amortization		(68,763)		(80,182)		(192,698)		(237,662)
Asset impairments		—		—		—		(24,977)
Goodwill impairment		—		—		—		(132,026)
Interest expense, net		(9,389)		(11,156)		(29,595)		(34,799)
Income tax expense		(234)		(293)		(227)		(111)
Net income (loss) attributable to ARLP	$	57,548	$	27,199	$	126,331	$	(164,248)
Noncontrolling interest		176		36		384		97
Net income (loss)	$	57,724	$	27,235	$	126,715	$	(164,151)

Segment Adjusted EBITDA Expense (a non-GAAP financial measure) includes operating expenses, coal purchases and other expense. Transportation expenses are excluded as these expenses are passed through to our customers and, consequently, we do not realize any gain or loss on transportation revenues. Segment Adjusted EBITDA Expense is used as a supplemental financial measure by our management to assess the operating performance of our segments. Segment Adjusted EBITDA Expense is a key component of Segment Adjusted EBITDA in addition to coal sales, royalty revenues and other revenues. The exclusion of corporate general and administrative expenses from Segment Adjusted EBITDA Expense allows management to focus solely on the evaluation of segment operating performance as it primarily relates to our operating expenses.

The following is a reconciliation of consolidated Segment Adjusted EBITDA Expense to operating expense, the most comparable GAAP financial measure:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020

	(in thousands)
Segment Adjusted EBITDA Expense	$	239,350	$	216,750	$	651,571	$	638,989
Outside coal purchases		(6,065)		—		(6,179)		—
Other expense		(84)		(723)		(2,632)		(1,456)
Operating expenses (excluding depreciation, depletion and amortization)	$	233,201	$	216,027	$	642,760	$	637,533

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Liquidity and Capital Resources

Liquidity

We have historically satisfied our working capital requirements and funded our capital expenditures, investments and debt service obligations with cash generated from operations, cash provided by the issuance of debt or equity, borrowings under credit and securitization facilities and other financing transactions. We believe that existing cash balances, future cash flows from operations and investments, borrowings under credit facilities and cash provided from the issuance of debt or equity will be sufficient to meet our working capital requirements, capital expenditures and additional investments, debt payments, commitments and any distribution payments. Nevertheless, our ability to satisfy our working capital requirements, to fund planned capital expenditures, to service our debt obligations or to pay distributions will depend upon our future operating performance and access to and cost of financing sources, which will be affected by prevailing economic conditions generally, and in both the coal and oil & gas industries specifically, as well as other financial and business factors, some of which are beyond our control, including the COVID-19 pandemic. Based on our recent operating cash flow results, current cash position, anticipated future cash flows and sources of financing that we expect to have available, we anticipate remaining in compliance with the covenants of the Credit Agreement and expect to have sufficient liquidity to fund our operations and growth strategies. However, to the extent operating cash flow or access to and cost of financing sources are materially different than expected, future covenant compliance or liquidity may be adversely affected. Please read "Item 1A. Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2020.

In May 2018, the Board approved the establishment of a unit repurchase program authorizing us to repurchase up to $100 million of ARLP common units. The program has no time limit and we may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate us to repurchase any dollar amount or number of units. Since inception through September 30, 2021, we have purchased units for a total of $93.5 million under the program. During the nine months ended September 30, 2021, we did not repurchase and retire any units. The timing of any future unit repurchases and the ultimate number of units to be purchased will depend on a number of factors, including business and market conditions, our future financial performance, and other capital priorities. Please read "Part II - Item 2. Unregistered Sales of Equity Securities and Use of Proceeds" of this Quarterly Report on Form 10-Q for more information on unit repurchase program.

Cash Flows

Cash provided by operating activities was $311.0 million for the 2021 Period compared to $291.8 million for the 2020 Period. The increase in cash provided by operating activities was primarily due to an increase in net income adjusted for non-cash items and a favorable working capital change related to accounts payable, partially offset by unfavorable working capital changes related to trade receivables and inventories compared to the 2020 Period.

Net cash used in investing activities was $80.4 million for the 2021 Period compared to $108.9 million for the 2020 Period. The decrease in cash used in investing activities was primarily attributable to the decrease in capital expenditures and an increase in accounts payable and certain other accruals related to mine infrastructure, equipment and mining operations at various mines during the 2021 Period.

Net cash used in financing activities was $181.5 million for the 2021 Period compared to $185.2 million for the 2020 Period. The decrease in cash used in financing activities was primarily attributable to lower cash distributions paid to unitholders, reduced borrowings and payments on the revolving credit facility, partially offset by increased payments and reduced borrowings on the securitization facility compared to the 2020 Period. A quarterly cash distribution of $0.40 per unit was paid in February 2020, after which payment of distributions to unitholders was temporarily suspended. Payment of quarterly distributions resumed in the 2021 Period with $0.20 per unit in total being paid for the first two quarters of the 2021 Period. Please read "Item 1. Financial Statements (Unaudited)—Note 10 – Partners' Capital" of this Quarterly Report on Form 10-Q regarding the subsequent quarterly distribution to be paid for the 2021 Quarter.

Capital Expenditures

Capital expenditures decreased to $88.7 million in the 2021 Period from $102.8 million in the 2020 Period. The decrease is primarily related to the transition to a new reserve area at MC Mining in the 2020 Period and continued expense

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control and efficiency initiatives across all our operations. Also see our discussion of "Cash Flows" above concerning the decrease in capital expenditures.

We currently project average estimated annual maintenance capital expenditures over the next five-year period of approximately $4.90 per ton produced. Our anticipated total capital expenditures, including maintenance capital expenditures, for 2021 are estimated in a range of $125.0 million to $130.0 million. Management anticipates funding remaining 2021 capital requirements with our cash and cash equivalents ($104.6 million as of September 30, 2021), cash flows from operations and investments, borrowings under revolving credit and securitization facilities and cash provided from the issuance of debt or equity. We will continue to have significant capital requirements over the long term, which may require us to incur debt or seek additional equity capital. The availability and cost of additional capital will depend upon prevailing market conditions, the market price of our common units and several other factors over which we have limited control, as well as our financial condition and results of operations.

Debt Obligations

Credit Facility. On March 9, 2020, our Intermediate Partnership entered into a Fifth Amended and Restated Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $459.5 million revolving credit facility, including a sublimit of $125 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings (the "Revolving Credit Facility"), with a termination date of March 9, 2024.

Senior Notes. On April 24, 2017, the Intermediate Partnership and Alliance Resource Finance Corporation (as co-issuer), a wholly owned subsidiary of the Intermediate Partnership ("Alliance Finance"), issued an aggregate principal amount of $400.0 million of senior unsecured notes due 2025 ("Senior Notes") in a private placement to qualified institutional buyers. The Senior Notes have a term of eight years, maturing on May 1, 2025 (the "Term") and accrue interest at an annual rate of 7.5%. Interest is payable semi-annually in arrears on each May 1 and November 1. The indenture governing the Senior Notes contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of distributions or similar restricted payments, undertaking transactions with affiliates and limitations on asset sales. The issuers of the Senior Notes may redeem all or a part of the notes at any time at redemption prices set forth in the indenture governing the Senior Notes.

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Accounts Receivable Securitization. On December 5, 2014, certain direct and indirect wholly owned subsidiaries of our Intermediate Partnership entered into a $100.0 million accounts receivable securitization facility ("Securitization Facility"). Under the Securitization Facility, certain subsidiaries sell certain trade receivables on an ongoing basis to our Intermediate Partnership, which then sells the trade receivables to AROP Funding, LLC ("AROP Funding"), a wholly owned bankruptcy-remote special purpose subsidiary of our Intermediate Partnership, which in turn borrows on a revolving basis up to $100.0 million secured by the trade receivables. After the sale, Alliance Coal, as servicer of the assets, collects the receivables on behalf of AROP Funding. The Securitization Facility bears interest based on a Eurodollar Rate. The agreement governing the Securitization Facility contains customary terms and conditions, including limitations with regards to certain customer credit ratings. In January 2021, we extended the term of the Securitization Facility to January 2022 and reduced the borrowing availability under the facility to $60.0 million. The Securitization Facility was previously scheduled to mature in January 2021. On September 30, 2021, we had no outstanding balance under the Securitization Facility.

May 2019 Equipment Financing. On May 17, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $10.0 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "May 2019 Equipment Financing"). The May 2019 Equipment Financing contains customary terms and events of default and provides for thirty-six monthly payments with an implicit interest rate of 6.25%, maturing on May 1, 2022. Upon maturity, the equipment will revert to the Intermediate Partnership.

November 2019 Equipment Financing. On November 6, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $53.1 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "November 2019 Equipment Financing"). The November 2019 Equipment Financing contains customary terms and events of default and an implicit interest rate of 4.75%, providing for a four-year term with forty-seven monthly payments of $1.0 million and a balloon payment of $11.6 million upon maturity on November 6, 2023. Upon maturity, the equipment will revert to the Intermediate Partnership.

June 2020 Equipment Financing. On June 5, 2020, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $14.7 million in exchange for conveying its interest in certain equipment owned indirectly by the Intermediate Partnership and entering into a master lease agreement for that equipment (the "June 2020 Equipment Financing"). The June 2020 Equipment Financing contains customary terms and events of default and provides for forty-eight monthly payments with an implicit interest rate of 6.1%, maturing on June 5, 2024. Upon maturity, the equipment will revert to the Intermediate Partnership.

Line of Credit. On February 19, 2021, we entered into a line of credit arrangement with a related party for $5.0 million. The line of credit has a maturity date of February 28, 2023, with an option to extend it for an additional six months and accrue interest at an annual rate of 3.50%. Interest is payable quarterly commencing March 31, 2021, and continuing each March 31, June 30, September 30 and December 31 thereafter through and including February 28, 2023. The agreement contains customary terms and events of default and is guaranteed by ARLP. We utilize the line of credit, as appropriate, for capital expenditures and investments. As of September 30, 2021, we had drawn $3.2 million under this agreement.

Other. We also have an agreement with a bank to provide additional letters of credit in an amount of $5.0 million to maintain surety bonds to secure certain asset retirement obligations and our obligations for workers' compensation benefits. On September 30, 2021, we had $5.0 million in letters of credit outstanding under this agreement.

Related-Party Transactions

We have related-party transactions and activities with Mr. Craft, MGP and their respective affiliates. These related-party transactions and activities relate principally to 1) coal mineral leases with The Joseph W. Craft III Foundation and The Kathleen S. Craft Foundation, 2) the use of aircraft, and 3) providing administrative services with respect to certain oil & gas mineral interests Mr. Craft acquired in 2019. We also have related-party transactions with (a) WKY CoalPlay, LLC ("WKY CoalPlay") regarding four mineral leases, (b) Bluegrass Minerals Management, LLC ("Bluegrass Minerals") through its noncontrolling ownership interest in our consolidated subsidiary, Cavalier Minerals and (c) with our equity interest in AllDale III. For more information regarding the Bluegrass Minerals and AllDale III, please read "Item 1. Financial Statements (Unaudited)—Note 8 – Variable Interest Entities" and "—Note 9 – Investment" of this

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Quarterly Report on Form 10-Q. We also have a line of credit with a related party as discussed in "Item 1. Financial Statements (Unaudited)—Note 7 – Long-Term Debt" of this Quarterly Report on Form 10-Q. Please read our Annual Report on Form 10-K for the year ended December 31, 2020, "Item 8. Financial Statements and Supplementary Data—Note 21 – Related-Party Transactions" for additional information concerning related-party transactions.

Other Information

Insurance

Effective October 1, 2021, we extended our existing annual property and casualty insurance program until December 1, 2021 at which time we plan to renew the program. Our property insurance was procured from our wholly owned captive insurance company, Wildcat Insurance. Wildcat Insurance charged certain of our subsidiaries for the premiums on this program and in return purchased reinsurance for the program in the standard market. The maximum limit in the commercial property program is $100.0 million per occurrence, excluding a $1.5 million deductible for property damage, a 75- or 90-day waiting period for underground business interruption depending on the mining complex and an additional $10.0 million overall aggregate deductible. We have elected to retain a 10% participating interest in our commercial property insurance program. We can make no assurances that we will not experience significant insurance claims in the future that could have a material adverse effect on our business, financial condition, results of operations and ability to purchase property insurance in the future. Also, exposures exist for which no insurance may be available and for which we have not reserved. In addition, the insurance industry has been subject to efforts by environmental activists to restrict coverages available for fossil fuel companies.

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

We have significant long-term coal sales contracts. Most of the long-term sales contracts are subject to price adjustment provisions, which periodically permit an increase or decrease in the contract price, typically to reflect changes in specified indices or changes in production costs resulting from regulatory changes, or both.

Our results of operations are highly dependent upon the prices we receive for our coal, oil and natural gas. Regarding coal, the short-term sales contracts favored by some of our coal customers leave us more exposed to risks of declining coal price periods. Regarding oil & natural gas, significant decline in prices would have a significant impact on our oil & gas royalty revenues.

We have exposure to coal and oil & gas sales prices and price risk for supplies that are used directly or indirectly in the normal course of coal and oil & gas production such as steel, electricity and other supplies. We manage our risk for these items through strategic sourcing contracts for normal quantities required by our operations. Historically, we have not utilized any commodity price-hedges or other derivatives related to either our sales price or supply cost risks but may do so in the future.

Credit Risk

Most of our coal is sold to United States electric utilities or into the international markets through brokered transactions. Therefore, our credit risk is primarily with domestic electric power generators and reputable global brokerage firms. Our policy is to independently evaluate each customer's creditworthiness prior to entering into transactions and to constantly monitor outstanding accounts receivable. When deemed appropriate by our credit management department, we will take steps to reduce our credit exposure to customers that do not meet our credit standards or whose credit has deteriorated. These steps may include obtaining letters of credit or cash collateral, requiring prepayment for shipments or establishing customer trust accounts held for our benefit in the event of a failure to pay. Such credit risks from customers may impact the borrowing capacity of our Securitization Facility. See "Part I - Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations—Debt Obligations – Accounts Receivable Securitization".

Exchange Rate Risk

Almost all our transactions are denominated in United States dollars, and as a result, we do not have material exposure to currency exchange-rate risks. However, because coal is sold internationally in United States dollars, general

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economic conditions in foreign markets and changes in foreign currency exchange rates may provide our foreign competitors with a competitive advantage. If our competitors' currencies decline against the United States dollar or against foreign purchasers' local currencies, those competitors may be able to offer lower prices for coal to these purchasers. Furthermore, if the currencies of overseas purchasers were to significantly decline in value in comparison to the United States dollar, those purchasers may seek decreased prices for the coal we sell to them. Consequently, currency fluctuations could adversely affect the competitiveness of our coal in international markets.

Interest Rate Risk

Borrowings under the Revolving Credit Facility and Securitization Facility are at variable rates and, as a result, we have interest rate exposure. Historically, our earnings have not been materially affected by changes in interest rates and we have not utilized interest rate derivative instruments related to our outstanding debt. We had no outstanding borrowings under the Revolving Credit Facility or the Securitization Facility on September 30, 2021.

There were no other changes in our quantitative and qualitative disclosures about market risk as set forth in our Annual Report on Form 10-K for the year ended December 31, 2020.

ITEM 4.CONTROLS AND PROCEDURES

We maintain controls and procedures designed to provide reasonable assurance that information required to be disclosed in the reports we file with the Securities and Exchange Commission ("SEC") is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow for timely decisions regarding required disclosure. 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 Chief Executive Officer and Chief Financial Officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act) as of September 30, 2021. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these controls and procedures are effective as of September 30, 2021.

During the quarterly period ended September 30, 2021, there have not been any changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) identified in connection with our evaluation that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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FORWARD-LOOKING STATEMENTS

Certain statements and information in this Quarterly Report on Form 10-Q, and certain oral statements made from time to time by our representatives, constitute "forward-looking statements." These statements are based on our beliefs as well as assumptions made by, and information currently available to, us. When used in this document, the words "anticipate," "believe," "continue," "could," "estimate," "expect," "forecast," "foresee," "may," "outlook," "plan," "project," "potential," "should," "will," "would," and similar expressions identify forward-looking statements. Without limiting the foregoing, all statements relating to our future outlook, anticipated capital expenditures, future cash flows and borrowings and sources of funding are forward-looking statements. These forward-looking statements are based on our current expectations and beliefs concerning future developments and reflect our current views with respect to future events and are subject to numerous assumptions that we believe are reasonable, but are open to a wide range of uncertainties and business risks, and actual results could differ materially from those discussed in these statements. Among the factors that could cause actual results to differ from those in the forward-looking statements are:

●

the severity, magnitude and duration of the COVID-19 pandemic, including impacts of the pandemic and of businesses' and governments' responses to the pandemic on our operations and personnel, and on demand for coal, oil and natural gas, the financial condition of our customers and suppliers, available liquidity and capital sources and broader economic disruptions;

●

changes in macroeconomic and market conditions and market volatility arising from the COVID-19 pandemic, including coal, oil, natural gas and natural gas liquids prices, and the impact of such changes and volatility on our financial position;

●

decline in the coal industry's share of electricity generation, including as a result of environmental concerns related to coal mining and combustion and the cost and perceived benefits of other sources of electricity and fuels, such as oil & gas, nuclear energy, and renewable fuels;

●

changing global economic conditions or in industries in which our customers operate;

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changes in coal prices and/or oil & gas prices, demand and availability which could affect our operating results and cash flows;

●

actions of the major oil producing countries with respect to oil production volumes and prices could have direct and indirect impacts over the near and long term on oil & gas exploration and production operations at the properties in which we hold mineral interests;

●

the effectiveness or lack of effectiveness in distributed vaccines to reduce the impact of COVID-19;

●

changes in competition in domestic and international coal markets and our ability to respond to such changes;

●

potential shut-ins of production by operators of the properties in which we hold mineral interests due to low oil, natural gas and natural gas liquid prices or the lack of downstream demand or storage capacity;

●

risks associated with the expansion of our operations and properties;

●

our ability to identify and complete acquisitions;

●

dependence on significant customer contracts, including renewing existing contracts upon expiration;

●

adjustments made in price, volume, or terms to existing coal supply agreements;

●

recent action and the possibility of future action on trade made by United States and foreign governments;

●

the effect of changes in taxes or tariffs and other trade measures;

●

legislation, regulations, and court decisions and interpretations thereof, both domestic and foreign, including those relating to the environment and the release of greenhouse gases, mining, miner health and safety, hydraulic fracturing, and health care;

●

deregulation of the electric utility industry or the effects of any adverse change in the coal industry, electric utility industry, or general economic conditions;

●

investors' and other stakeholders' increasing attention to environmental, social and governance matters;

●

liquidity constraints, including those resulting from any future unavailability of financing;

●

customer bankruptcies, cancellations or breaches to existing contracts, or other failures to perform;

●

customer delays, failure to take coal under contracts or defaults in making payments;

●

our productivity levels and margins earned on our coal sales;

●

disruptions to oil & gas exploration and production operations at the properties in which we hold mineral interests;

●

changes in raw material costs;

●

changes in the availability of skilled labor;

●

our ability to maintain satisfactory relations with our employees;

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●

increases in labor costs including costs of health insurance and taxes resulting from the Affordable Care Act, adverse changes in work rules, or cash payments or projections associated with workers' compensation claims;

●

increases in transportation costs and risk of transportation delays or interruptions;

●

operational interruptions due to geologic, permitting, labor, weather-related or other factors;

●

risks associated with major mine-related accidents, mine fires, mine floods or other interruptions;

●

results of litigation, including claims not yet asserted;

●

foreign currency fluctuations that could adversely affect the competitiveness of our coal abroad;

●

difficulty maintaining our surety bonds for mine reclamation as well as workers' compensation and black lung benefits;

●

difficulty in making accurate assumptions and projections regarding post-mine reclamation as well as pension, black lung benefits, and other post-retirement benefit liabilities;

●

uncertainties in estimating and replacing our coal reserves;

●

uncertainties in estimating and replacing our oil & gas reserves;

●

uncertainties in the amount of oil & gas production due to the level of drilling and completion activity by the operators of our oil & gas properties;

●

the impact of current and potential changes to federal or state tax rules and regulations, including a loss or reduction of benefits from certain tax deductions and credits;

●

difficulty obtaining commercial property insurance, and risks associated with our participation in the commercial insurance property program;

●

evolving cybersecurity risks, such as those involving unauthorized access, denial-of-service attacks, malicious software, data privacy breaches by employees, insiders or others with authorized access, cyber or phishing-attacks, ransomware, malware, social engineering, physical breaches or other actions;

●

difficulty in making accurate assumptions and projections regarding future revenues and costs associated with equity investments in companies we do not control; and

●

other factors, including those discussed in "Item 1A. Risk Factors" and "Item 3. Legal Proceedings" in our Annual Report on Form 10-K for the year ended December 31, 2020.

If one or more of these or other risks or uncertainties materialize, or should our underlying assumptions prove incorrect, our actual results could differ materially from those described in any forward-looking statement. When considering forward-looking statements, you should also keep in mind our risk factors and legal proceedings. Known material factors that could cause our actual results to differ from those in the forward-looking statements are described in "Item 1. Legal Proceedings" and "Item 1A. Risk Factors" below. We disclaim any obligation to update or revise any forward-looking statements or to announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments, unless required by law.

You should consider the information above when reading or considering any forward-looking statements contained in:

●

this Quarterly Report on Form 10-Q;

●

other reports filed by us with the SEC;

●

our press releases;

●

our website http://www.arlp.com; and

●

written or oral statements made by us or any of our officers or other authorized persons acting on our behalf.

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PART II

OTHER INFORMATION

ITEM 1.LEGAL PROCEEDINGS

Litigation was initiated in November 2019 in the U.S. District Court for the Western District of Kentucky (Branson v. Webster County Coal, LLC et al.) against certain of our subsidiaries in which the plaintiffs allege violations of the Fair Labor Standards Act and Kentucky Wage and Hour Act due to alleged failure to compensate for time "donning" and "doffing" equipment and to account for certain bonuses in the calculation of overtime rates and pay. The plaintiffs seek class or collective action certification. A similar lawsuit was initiated in March 2020 in the U.S. District Court for the Eastern District of Kentucky (Brewer v. Alliance Coal, LLC, et al.). Collectively, the plaintiffs of these two lawsuits allege damages ranging from approximately $22.2 million to $143.7 million. Subsequently, four additional lawsuits making similar allegations were initiated against certain of our subsidiaries: filed March 4, 2021 in the Circuit Court for Hopkins County, Kentucky (Johnson v. Hopkins County Coal, LLC, et al.); filed April 6, 2021 in the U.S. District Court for the Northern District of West Virginia (Rettig v. Mettiki Coal WV, LLC, et al.); filed April 9, 2021 in the U.S. District Court for the Southern District of Illinois (Cates v. Hamilton County Coal, LLC, et al.); and filed April 13, 2021 in the U.S. District Court for the Southern District of Indiana (Prater v. Gibson County Coal, LLC, et al.). We believe the claims made in these lawsuits are without merit and intend to defend the litigation vigorously. The litigation is in early stages. We do not believe this litigation will have a material adverse effect on our business, financial position or results of operations.

ITEM 1A.RISK FACTORS

In addition to the other information set forth in this Quarterly Report on Form 10-Q, you should carefully consider the risk factors discussed in Part I - Item 1A. "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2020, which could materially affect our business, financial condition or future results. The risks described in these reports are not our only risks. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial based on current knowledge and factual circumstances, if such knowledge or facts change, also may materially adversely affect our business, financial condition and/or operating results in the future.

ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

On May 31, 2018, ARLP announced that the MGP board of directors approved the establishment of a unit repurchase program authorizing ARLP to repurchase up to $100 million of its outstanding limited partner common units. The unit repurchase program is intended to enhance ARLP's ability to achieve its goal of creating long-term value for its unitholders and provides another means, along with quarterly cash distributions, of returning cash to unitholders. The program has no time limit and ARLP may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate ARLP to repurchase any dollar amount or number of units and repurchases may be commenced or suspended from time to time without prior notice.

During the three months ended September 30, 2021, we did not repurchase and retire any units. Since inception of the unit repurchase program, we have repurchased and retired 5,460,639 units at an average unit price of $17.12 for an aggregate purchase price of $93.5 million.

ITEM 3.DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.MINE SAFETY DISCLOSURES

Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95.1 to this Quarterly Report on Form 10-Q.

ITEM 5.OTHER INFORMATION

None.

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ITEM 6.EXHIBITS


		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*

3.1	Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 17990766	3.2	07/28/2017

3.2	Amendment No. 1 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	10-K	000-26823 18634634	3.9	02/23/2018

3.3	Amendment No. 2 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 18883834	3.3	06/06/2018

3.4	Amendment No. 3 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 18883834	3.4	06/06/2018

3.5	Amended and Restated Agreement of Limited Partnership of Alliance Resource Operating Partners, L.P.	10-K	000-26823 583595	3.2	03/29/2000

3.6	Amendment No. 1 to Amended and Restated Agreement of Limited Partnership of Alliance Resource Operating Partners, L.P.	8-K	000-26823 18883834	3.5	06/06/2018

3.7	Amended and Restated Certificate of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 17990766	3.6	07/28/2017

3.8	Certificate of Limited Partnership of Alliance Resource Operating Partners, L.P.	S-1/A	333-78845 99669102	3.8	07/23/1999

3.9	Certificate of Formation of Alliance Resource Management GP, LLC	S-1/A	333-78845 99669102	3.7	07/23/1999

3.10	Third Amended and Restated Operating Agreement of Alliance Resource Management GP, LLC	8-K	000-26823 18883834	3.7	06/06/2018

3.11	Certificate of Formation of MGP II, LLC	8-K	000-26823 17990766	3.5	07/28/2017

3.12	Amended and Restated Operating Agreement of MGP II, LLC	8-K	000-26823 17990766	3.4	07/28/2017

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		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*

31.1	Certification of Joseph W. Craft III, President and Chief Executive Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 4, 2021, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2	Certification of Brian L. Cantrell, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 4, 2021, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certification of Joseph W. Craft III, President and Chief Executive Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 4, 2021, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2	Certification of Brian L. Cantrell, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 4, 2021, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

95.1	Federal Mine Safety and Health Act Information

101	Interactive Data File (Form 10-Q for the quarter ended September 30, 2021 filed in Inline XBRL).

104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

* Or furnished, in the case of Exhibits 32.1 and 32.2.

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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, in Tulsa, Oklahoma, on November 4, 2021.


	ALLIANCE RESOURCE PARTNERS, L.P.

	By:	Alliance Resource Management GP, LLC
		its general partner

		/s/ Joseph W. Craft, III

		Joseph W. Craft, III
		President, Chief Executive Officer
		and Chairman, duly authorized to sign on behalf of the registrant.


		/s/ Robert J. Fouch

		Robert J. Fouch
		Vice President, Controller and
		Chief Accounting Officer

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