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, 2023

OR

☐   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 8, 2023, 127,125,437 common units are outstanding.

TABLE OF CONTENTS

		Page
ITEM 1.	Financial Statements (Unaudited)
	ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
	Condensed Consolidated Balance Sheets as of September 30, 2023 and December 31, 2022	1
	Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2023 and 2022	2
	Condensed Consolidated Statements of Comprehensive Income for the three and nine months ended September 30, 2023 and 2022	3
	Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2023 and 2022	4
	Notes to Condensed Consolidated Financial Statements	5
	1.     Organization and Presentation	5
	2.     Acquisitions	6
	3.     Contingencies	7
	4.     Inventories	7
	5.     Fair Value Measurements	7
	6.     Long-Term Debt	8
	7.     Income Taxes	10
	8.    Variable Interest Entities	11
	9.    Equity Investments	12
	10.   Partners' Capital	14
	11.   Revenue from Contracts with Customers	17
	12.   Earnings per Limited Partner Unit	18
	13.   Workers' Compensation and Pneumoconiosis	19
	14.   Common Unit-Based Compensation Plans	20
	15.   Components of Pension Plan Net Periodic Benefit Cost	21
	16.   Segment Information	21
ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	25
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	38
ITEM 4.	Controls and Procedures	39
	Forward-Looking Statements	40
PART II
OTHER INFORMATION
ITEM 1.	Legal Proceedings	42
ITEM 1A.	Risk Factors	42
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	42
ITEM 3.	Defaults Upon Senior Securities	43
ITEM 4.	Mine Safety Disclosures	43
ITEM 5.	Other Information	43
ITEM 6.	Exhibits	43

i

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,
	2023		2022*
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	197,243	$	296,023
Trade receivables		220,138		241,412
Other receivables		13,854		8,601
Inventories, net		135,868		77,326
Advance royalties		5,824		7,556
Prepaid expenses and other assets		14,962		26,675
Total current assets		587,889		657,593
PROPERTY, PLANT AND EQUIPMENT:
Property, plant and equipment, at cost		4,133,738		3,931,422
Less accumulated depreciation, depletion and amortization		(2,152,278)		(2,050,754)
Total property, plant and equipment, net		1,981,460		1,880,668
OTHER ASSETS:
Advance royalties		73,798		67,713
Equity method investments		44,966		49,371
Equity securities		92,541		42,000
Operating lease right-of-use assets		17,249		14,950
Other long-term assets		16,138		15,726
Total other assets		244,692		189,760
TOTAL ASSETS	$	2,814,041	$	2,728,021
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable	$	116,819	$	95,122
Accrued taxes other than income taxes		22,516		22,967
Accrued payroll and related expenses		40,803		39,623
Accrued interest		10,631		5,000
Workers' compensation and pneumoconiosis benefits		14,052		14,099
Other current liabilities		30,715		53,790
Current maturities, long-term debt, net		38,603		24,970
Total current liabilities		274,139		255,571
LONG-TERM LIABILITIES:
Long-term debt, excluding current maturities, net		321,208		397,203
Pneumoconiosis benefits		102,193		100,089
Accrued pension benefit		11,770		12,553
Workers' compensation		41,303		39,551
Asset retirement obligations		143,707		142,254
Long-term operating lease obligations		14,358		12,132
Deferred income tax liabilities		34,343		35,814
Other liabilities		18,092		24,828
Total long-term liabilities		686,974		764,424
Total liabilities		961,113		1,019,995
COMMITMENTS AND CONTINGENCIES - (NOTE 3)
PARTNERS' CAPITAL:
ARLP Partners' Capital:
Limited Partners - Common Unitholders 127,125,437 and 127,195,219 units outstanding, respectively		1,867,721		1,656,025
General Partner's interest		—		66,548
Accumulated other comprehensive loss		(39,365)		(41,054)
Total ARLP Partners' Capital		1,828,356		1,681,519
Noncontrolling interest		24,572		26,507
Total Partners' Capital		1,852,928		1,708,026
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$	2,814,041	$	2,728,021

*Recast as discussed in Note 1 – Organization and Presentation.

See notes to condensed consolidated financial statements.

1

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except unit and per unit data)

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022*		2023		2022*
SALES AND OPERATING REVENUES:
Coal sales	$	549,123	$	550,563	$	1,688,238	$	1,470,730
Oil & gas royalties		34,125		38,695		101,709		111,378
Transportation revenues		34,964		28,548		95,729		93,305
Other revenues		18,309		14,655		55,603		40,348
Total revenues		636,521		632,461		1,941,279		1,715,761
EXPENSES:
Operating expenses (excluding depreciation, depletion and amortization)		339,099		330,694		1,012,224		909,567
Transportation expenses		34,964		28,548		95,729		93,305
Outside coal purchases		11,530		—		15,739		151
General and administrative		20,097		21,360		61,312		62,462
Depreciation, depletion and amortization		65,393		70,669		199,582		202,499
Total operating expenses		471,083		451,271		1,384,586		1,267,984
INCOME FROM OPERATIONS		165,438		181,190		556,693		447,777
Interest expense (net of interest capitalized for the three and nine months ended September 30, 2023 and 2022 of $1,809, $264, $4,432 and $505, respectively)		(7,736)		(9,245)		(29,845)		(28,304)
Interest income		2,669		426		8,084		554
Equity method investment income (loss)		(1,842)		2,108		(3,784)		4,576
Other income (expense)		223		193		(173)		1,339
INCOME BEFORE INCOME TAXES		158,752		174,672		530,975		425,942
INCOME TAX EXPENSE		3,401		6,600		11,641		55,646
NET INCOME		155,351		168,072		519,334		370,296
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST		(1,652)		(364)		(4,660)		(977)
NET INCOME ATTRIBUTABLE TO ARLP	$	153,699	$	167,708	$	514,674	$	369,319
NET INCOME ATTRIBUTABLE TO ARLP
GENERAL PARTNER	$	—	$	3,101	$	1,384	$	6,582
LIMITED PARTNERS	$	153,699	$	164,607	$	513,290	$	362,737
EARNINGS PER LIMITED PARTNER UNIT - BASIC AND DILUTED	$	1.18	$	1.25	$	3.93	$	2.76
WEIGHTED-AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED		127,125,437		127,195,219		127,198,805		127,195,219

* Recast as discussed in Note 1 – Organization and Presentation.

See notes to condensed consolidated financial statements.

2

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022*		2023		2022*
NET INCOME	$	155,351	$	168,072	$	519,334	$	370,296
OTHER COMPREHENSIVE INCOME:
Defined benefit pension plan
Amortization of prior service cost (1)		47		47		140		140
Amortization of net actuarial loss (1)		169		495		513		1,467
Total defined benefit pension plan adjustments		216		542		653		1,607
Pneumoconiosis benefits
Amortization of net actuarial loss (1)		345		260		1,036		779
Total pneumoconiosis benefits adjustments		345		260		1,036		779
OTHER COMPREHENSIVE INCOME		561		802		1,689		2,386
COMPREHENSIVE INCOME		155,912		168,874		521,023		372,682
Less: Comprehensive income attributable to noncontrolling interest		(1,652)		(364)		(4,660)		(977)
COMPREHENSIVE INCOME ATTRIBUTABLE TO ARLP	$	154,260	$	168,510	$	516,363	$	371,705

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

* Recast as discussed in Note 1 – Organization and Presentation.

See notes to condensed consolidated financial statements.

3

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

	Nine Months Ended
	September 30,
	2023		2022*
CASH FLOWS FROM OPERATING ACTIVITIES	$	735,411	$	556,206
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, plant and equipment:
Capital expenditures		(295,356)		(221,286)
Change in accounts payable and accrued liabilities		(23,006)		39,500
Proceeds from sale of property, plant and equipment		3,436		5,006
Contributions to equity method investments		(2,257)		(20,220)
Purchase of equity securities		(49,560)		(32,639)
JC Resources acquisition		(64,999)		—
Payments for acquisitions of businesses		—		(11,391)
Escrow deposit for oil & gas reserve acquisition		—		(4,150)
Oil & gas reserve acquisition		(13,902)		—
Other		1,160		(2,317)
Net cash used in investing activities		(444,484)		(247,497)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under securitization facility		—		27,500
Payments under securitization facility		—		(27,500)
Payments on equipment financings		(11,421)		(12,360)
Borrowing under long-term debt		75,000		—
Payments on long-term debt		(120,080)		—
Payments on finance lease obligations		(334)		(623)
Payment of debt issuance costs		(11,744)		—
Payments for purchases of units under unit repurchase program		(19,432)		—
Payments for tax withholdings related to settlements under deferred compensation plans		(10,334)		—
Excess purchase price over the contributed basis from JC Resources acquisition		(7,251)		—
Cash retained by JC Resources in acquisition		(2,933)		(7,652)
Distributions paid to Partners		(273,767)		(130,898)
Other		(7,411)		(1,108)
Net cash used in financing activities		(389,707)		(152,641)
NET CHANGE IN CASH AND CASH EQUIVALENTS		(98,780)		156,068
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		296,023		122,403
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	197,243	$	278,471
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest	$	22,411	$	18,708
Cash paid for income taxes	$	10,420	$	17,404
SUPPLEMENTAL NON-CASH ACTIVITY:
Accounts payable for purchase of property, plant and equipment	$	21,275	$	47,825
Right-of-use assets acquired by operating lease	$	2,596	$	1,291
Market value of common units issued under deferred compensation plans before tax withholding requirements	$	28,906	$	—

* Recast as discussed in Note 1 – Organization and Presentation.

See notes to condensed consolidated financial statements.

4

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, an indirect wholly owned subsidiary of ARLP.

● References to "Alliance Minerals" mean Alliance Minerals, LLC, an indirect wholly owned subsidiary of ARLP.

● References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, an indirect wholly owned subsidiary of ARLP.

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.

JC Resources Acquisition

On February 22, 2023, we acquired approximately 2,682 oil & gas net royalty acres in the Delaware Basin from JC Resources LP ("JC Resources"), an entity owned by Mr. Craft, for $72.3 million, which was funded with cash on hand ("JC Resources Acquisition"). Because JC Resources is owned by Mr. Craft, the JC Resources Acquisition is accounted for as a reorganization of entities under common control, whereby the assets and liabilities acquired from JC Resources are combined with the ARLP Partnership at their historical amounts for all periods presented.  The recasting of 2022 for the JC Resources Acquisition increased revenues by $4.0 million and $10.0 million for the three and nine months ended September 30, 2022, respectively, and increased income from operations, net income and comprehensive income by $3.1 million and $6.6 million for the three and nine months ended September 30, 2022, respectively. We did not recast historical earnings per limited partner unit as pre-acquisition earnings from the JC Resources Acquisition were allocated to our general partner. For more information on this acquisition please see Note 2 – Acquisitions.

Ascend Investment

On August 22, 2023, we purchased $25.0 million of Series D Preferred Stock (the "Ascend Preferred Stock") from Ascend Elements, Inc. ("Ascend"), a U.S.-based manufacturer and recycler of sustainable, engineered battery materials for electric vehicles.  The Ascend Preferred Stock provides for non-cumulative dividends when and if declared by Ascend's board of directors.  Each share is convertible, at any time, at our option, into shares of common stock of Ascend.  Our investment in Ascend furthers our business strategy to pursue opportunities that support the advancement of energy and related infrastructure and leverage our core competencies and relationships.  For more information on this investment please see Note 9 – Equity Investments.

5

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, 2023 and December 31, 2022, the results of our operations and comprehensive income for the three and nine months ended September 30, 2023 and 2022, and cash flows for the nine months ended September 30, 2023 and 2022.  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, 2022.

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, 2023.

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.

Cash and Cash Equivalents

Cash and cash equivalents include cash on hand and on deposit, including highly liquid investments with maturities of three months or less. At times the ARLP Partnership maintains deposits in federally insured financial institutions in excess of stated federally insured limits.  Management monitors the credit ratings and concentration of risk with these financial institutions on a continuing basis to safeguard cash deposits. Based on this monitoring and other diligence, including discussions with representatives of the financial institutions, we have no reason to believe that any of the financial institutions in which we have deposits in excess of stated federally insured limits are facing financial difficulties, defaults or limited liquidity situations that would cause us to be unable to access to our deposits.

2.ACQUISITIONS

JC Resources

As discussed in Note 1 – Organization and Presentation, on February 22, 2023, we completed the JC Resources Acquisition, which gives us increased exposure to a prolific area of the Delaware Basin that is within close proximity to reserves that we currently own.  This acquisition was approved by the conflicts committee of MGP's board of directors, which is comprised entirely of independent directors.  Because JC Resources is under common control with us, we recorded the acquisition at JC Resources' carrying value for each period presented. The carrying value of the mineral interests as well as related receivables and payables at February 22, 2023 was $65.0 million inclusive of $25.4 million and $37.8 million of mineral interests in proved and unproved properties, respectively. The JC Resources Acquisition increased revenues included in our condensed consolidated statements of income by $3.0 million and $8.3 million for the three and nine months ended September 30, 2023, respectively.

Acquisition Agreement

On January 27, 2023, we entered into a one-year collaborative agreement with a third party, effective January 1, 2023, committing up to $35.0 million for the acquisition of oil & gas mineral interests in the Midland and Delaware Basins. Under the agreement, the third party assists us in the identification, evaluation, and acquisition of target oil & gas mineral interests. In exchange for these services, the third party receives a participation share, partially funded by the third party, and is paid a periodic management fee.  As of September 30, 2023, we have purchased $4.0 million and $3.8 million of

6

oil & gas mineral interests in proved and unproved properties, respectively, pursuant to this agreement.  Management fees paid under this agreement have been immaterial.

Miscellaneous Acquisitions

In addition to the acquisitions under the collaborative agreement discussed above, we purchased $3.6 million and $2.5 million of oil & gas mineral interests in proved and unproved properties, respectively, within the Midland and Delaware Basins during the nine months ended September 30, 2023.

3.CONTINGENCIES

Certain of our subsidiaries are party to litigation in which the plaintiffs allege violations of the Fair Labor Standards Act and state law 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 and collective action certification, which we oppose, and the courts have not yet made definitive final rulings on those issues. We believe our ultimate exposure, if any, will not be material to our results of operations or financial position; however, if our current belief as to the merit of the claims 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 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.

4.INVENTORIES

Inventories consist of the following:

	September 30,		December 31,
	2023		2022
	(in thousands)
Coal	$	67,965	$	23,553
Supplies (net of reserve for obsolescence of $7,869 and $6,601, respectively)		67,903		53,773
Total inventories, net	$	135,868	$	77,326

During the nine months ended September 30, 2023, we recorded lower of cost or net realizable value adjustments of $14.2 million to our coal inventories as a result of lower coal sale prices and higher cost per ton primarily due to the impact of the Mettiki longwall being idle since June 2023 as a result of delayed development of a new longwall district.

5.FAIR VALUE MEASUREMENTS

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

	September 30, 2023						December 31, 2022
	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
	(in thousands)
Long-term debt	$	—	$	369,985	$	—	$	—	$	424,420	$	—
Total	$	—	$	369,985	$	—	$	—	$	424,420	$	—

7

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 6 – 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.

6.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,
	2023		2022		2023		2022
	(in thousands)
Revolving credit facility	$	—	$	—	$	(8,207)	$	(2,702)
Term loan		70,312		—		(1,432)		—
Senior notes		284,608		400,000		(1,058)		(2,134)
Securitization facility		—		—		—		—
November 2019 equipment financing		12,552		21,072		—		—
June 2020 equipment financing		3,036		5,937		—		—
		370,508		427,009		(10,697)		(4,836)
Less current maturities		(39,026)		(24,970)		423		—
Total long-term debt	$	331,482	$	402,039	$	(10,274)	$	(4,836)

Credit Facility

On January 13, 2023, Alliance Coal, as borrower, entered into a Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $425 million revolving credit facility, which includes a sublimit of $15.0 million for swingline borrowings and permits the issuance of letters of credit up to the full amount of $425 million (the "Revolving Credit Facility"), and for a term loan in an aggregate principal amount of $75 million (the "Term Loan"). The Credit Agreement matures on March 9, 2027, at which time the aggregate outstanding principal amount of all Revolving Credit Facility advances and all Term Loan advances are required to be repaid in full. The Credit Agreement will instead mature on January 30, 2025, if on that date our Senior Notes, as discussed below, are still outstanding and Alliance Coal does not have liquidity of at least $200 million. Interest is payable quarterly, with principal of the Term Loan due in quarterly installments equal to 6.25% of the original principal amount of the Term Loan beginning with the quarter ending June 30, 2023 and the balance payable at maturity. The Revolving Credit Facility replaces the $459.5 million revolving credit facility, which included a sublimit of $125.0 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings, extended to the Intermediate Partnership under its Fifth Amended and Restated Credit Agreement, dated as of March 9, 2020 that would have expired on March 9, 2024. We incurred debt issuance costs during the nine months ended September 30, 2023 of $11.7 million in connection with the Credit Agreement. These debt issuance costs are deferred and amortized as a component of interest expense over the term of the Revolving Credit Facility.

The Revolving Credit Facility is underwritten by a syndicate of eighteen financial institutions and the obligations of the lenders are individual obligations, which means the failure of one or more lenders to be able to fund its obligation does not relieve the remaining lenders from funding their obligations. Based on our diligence, including discussions with representatives of certain of these financial institutions, as of September 30, 2023 we have no reason to believe that the banks within our syndicate are facing financial difficulties, defaults or limited liquidity situations that would cause them to be unable to fund their obligations under the Credit Agreement. However, should any of the banks in our syndicate experience conditions in the future that limit their ability to fund their obligations, the amount available under the Revolving Credit Facility could be reduced.    

The Credit Agreement is guaranteed by ARLP and certain of its subsidiaries, including the Intermediate Partnership and most of the direct and indirect subsidiaries of Alliance Coal (the "Subsidiary Guarantors"). The Credit

8

Agreement also is secured by substantially all of the assets of the Subsidiary Guarantors and Alliance Coal. Borrowings under the Credit Agreement bear interest, at our option, at either (i) an adjusted one-month, three-month or six-month term rate based on the secured overnight financing rate published by the Federal Reserve Bank of New York, plus the applicable margin or (ii) the base rate plus the applicable margin. The base rate is the highest of (i) the Overnight Bank Funding Rate plus 0.50%, (ii) the Administrative Agent's prime rate, and (iii) the Daily Simple Secured Overnight Financing Rate plus 100 basis points. The applicable margin for borrowings under the Credit Agreement are determined by reference to the Consolidated Debt to Consolidated Cash Flow Ratio. For borrowings under the Term Loan, we elected the three-month term rate, with applicable margin, which was 8.55% as of September 30, 2023.  At September 30, 2023, we had $41.0 million of letters of credit outstanding with $384.0 million available for borrowing under the Revolving Credit Facility. We incurred an annual commitment fee of 0.50% on the undrawn portion of the Revolving Credit Facility. We utilize the Credit Agreement, as appropriate, for working capital requirements, capital expenditures and investments, scheduled debt payments and distribution payments.  

The Credit Agreement contains various restrictions affecting Alliance Coal and its subsidiaries, including, among other things, restrictions on incurrence of additional indebtedness and liens, sale of assets, investments, mergers and consolidations and transactions with affiliates. In each case, these restrictions are subject to various exceptions. In addition, restrictions apply to cash distributions by Alliance Coal to the Intermediate Partnership if such distribution would result in exceeding a minimum fixed charge coverage ratio (as determined in the Credit Agreement) or in Alliance Coal having liquidity of less than $200 million. The Credit Agreement requires us to maintain (a) a debt of Alliance Coal to cash flow ratio of not more than 1.5 to 1.0, (b) a consolidated debt of Alliance Coal and the Intermediate Partnership to cash flow ratio of not more than 2.5 to 1.0 and (c) an interest coverage ratio of not less than 3.0 to 1.0, in each case, during the four most recently ended fiscal quarters. The debt of Alliance Coal to cash flow ratio, consolidated debt of Alliance Coal and the Intermediate Partnership to cash flow ratio, and interest coverage ratio were 0.10 to 1.0, 0.43 to 1.0 and 95.83 to 1.0, respectively, for the trailing twelve months ended September 30, 2023. We were in compliance with the covenants of the Credit Agreement as of September 30, 2023 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 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. During the nine months ended September 30, 2023, we repurchased or redeemed $115.4 million of our Senior Notes. The gain on extinguishment of the Senior Notes is immaterial.  

Accounts Receivable Securitization

Certain direct and indirect wholly owned subsidiaries of our Intermediate Partnership are party to a $60.0 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 $60.0 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 short-term bank yield index. On September 30, 2023, we had $11.7 million of letters of credit outstanding with $48.3 million available for borrowing under the Securitization Facility. The agreement governing the Securitization Facility contains customary terms and conditions, including limitations with regards to certain customer credit ratings. In January 2023, we extended the term of the Securitization Facility to January 2024. The Securitization Facility was previously scheduled to mature in January 2023. At September 30, 2023, we did not have any outstanding borrowings under the Securitization Facility.

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

9

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 reverted 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.

7.INCOME TAXES

Components of income tax expense are as follows:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Current:
Federal	$	5,429	$	5,944	$	13,676	$	17,153
State		373		387		946		1,218
		5,802		6,331		14,622		18,371
Deferred:
Federal		(2,077)		267		(2,598)		34,932
State		(324)		2		(383)		2,343
		(2,401)		269		(2,981)		37,275
Income tax expense	$	3,401	$	6,600	$	11,641	$	55,646

On March 15, 2022, Alliance Minerals changed its U.S. federal income tax status from a pass-through entity to a taxable entity via a "check the box" election (the "Tax Election"), which became effective January 1, 2022. The Tax Election resulted in the recognition of an initial deferred tax liability of $37.3 million and a corresponding increase to income tax expense for the nine months ended September 30, 2022.

The effective income tax rate for our income tax expense for the three and nine months ended September 30, 2023 is less than the federal statutory rate, primarily due to the portion of income not subject to income taxes. The effective income tax rate for our income tax expense for the three and nine months ended September 30, 2022 is less than the federal statutory rate, primarily due to the portion of income not subject to income taxes, partially offset by the effect of the Tax Election.

Our 2020 through 2022 tax years remain open to examination by tax authorities, and lower-tier partnership income tax returns for the tax years ended December 31, 2020 and 2021 are being audited by the Internal Revenue Service.

10

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 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. All members have recovered their investment and Bluegrass Minerals began receiving its profits interest distributions in late 2022.  We hold the managing member interest in Cavalier Minerals.  

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 income.

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 – Equity Investments for more information.

Francis

On April 5, 2022, we invested $20 million in Francis Renewable Energy, LLC ("Francis"), in the form of a convertible note. Our convertible note matured on April 1, 2023 and was converted into a preferred equity interest in Francis.  Prior to conversion, we had determined the note more closely represented equity as opposed to debt. Therefore, we accounted for the convertible note as an equity contribution even though we did not participate in Francis' earnings or losses and were not eligible to receive distributions during the term of the note. Subsequent to the conversion on April 1, 2023, we participate in earnings and losses and are eligible to receive distributions. As of September 30, 2023, we held approximately 17.0% of Francis' equity.

We have concluded that Francis is a VIE as the management structure is similar to a limited partnership with the non-managing members (i) not having the ability to remove the managing member and (ii) not participating significantly in the operational decisions.  We are not the primary beneficiary of Francis as we do not have the power to direct the activities that most significantly impact Francis's economic performance. We account for our ownership interest in the income or loss of Francis as an equity method investment. Following the conversion of our note to preferred equity, we record equity income or loss based on Francis' distribution structure. See Note 9 – Equity Investments for more information.

11

NGP ET IV

On June 2, 2022, we committed to purchase $25.0 million of limited partner interests in NGP Energy Transition, L.P. ("NGP ET IV"), a private equity fund sponsored by NGP and focused on investments that are part of the global transition toward a lower carbon economy. This commitment represents a 3.6% interest in NGP ET IV. As of September 30, 2023, we have funded $6.3 million of this commitment.  

We have concluded that NGP ET IV is a VIE as it is structured as a limited partnership with limited partners (i) not having the ability to remove the general partner and (ii) not participating significantly in the operational decisions. We are not the primary beneficiary of NGP ET IV as we do not have the power to direct the activities that most significantly impact NGP ET IV's economic performance.  We account for our ownership interest in the income or loss of NGP ET IV as an equity method investment. See Note 9 – Equity Investments for more information.

9.           EQUITY INVESTMENTS

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 were as follows:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Beginning balance	$	24,451	$	26,278	$	25,284	$	26,325
Equity method investment income		578		2,108		1,719		4,576
Distributions received		(904)		(2,448)		(2,878)		(4,963)
Ending balance	$	24,125	$	25,938	$	24,125	$	25,938

Francis

As discussed in Note 8 – Variable Interest Entities, we account for our ownership interest in the income or loss of Francis as an equity method investment. Prior to the conversion of our convertible note, we did not participate in Francis' earnings or losses; however, upon conversion on April 1, 2023 we began participating. As a development stage company, Francis depends primarily on capital contributions to meet its operating and debt obligations.  We currently believe that the carrying value of our investment is recoverable; however, if Francis is unable to raise sufficient funds to continue its operations and meet its debt obligations, it could have an adverse effect on our investment. The changes in our equity method investment in Francis were as follows:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Beginning balance	$	17,380	$	20,000	$	20,000	$	—
Contributions		—		—		—		20,000
Equity method investment loss		(2,435)		—		(5,055)		—
Ending balance	$	14,945	$	20,000	$	14,945	$	20,000

12

NGP ET IV

As discussed in Note 8 – Variable Interest Entities, we account for our ownership interest in the income or loss of NGP ET IV as an equity method investment. The changes in our equity method investment in NGP ET IV were as follows:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Beginning balance	$	4,958	$	110	$	4,087	$	—
Contributions		923		110		2,257		220
Equity method investment income (loss)		15		—		(448)		—
Ending balance	$	5,896	$	220	$	5,896	$	220

Infinitum

During 2022, we purchased $42.0 million of Series D Preferred Stock ("Series D Preferred Stock") in Infinitum Electric, Inc. ("Infinitum"), a Texas-based startup developer and manufacturer of electric motors featuring printed circuit board stators.  On September 8, 2023, we purchased $24.6 million of Series E Preferred Stock ("Series E Preferred Stock" and, together with the "Series D Preferred Stock," the "Infinitum Preferred Stock") in Infinitum.  The Infinitum Preferred Stock provides for non-cumulative dividends when and if declared by Infinitum's board of directors. Each share of Infinitum Preferred Stock is convertible, at any time, at our option, into shares of common stock of Infinitum. We account for our ownership interest in Infinitum as an equity investment without a readily determinable fair value.  Absent an observable price change, it is not practicable to estimate the fair value of our investment in Infinitum because of the lack of a quoted market price for our ownership interests.  Therefore, we use a measurement alternative other than fair value to account for our investment.

Ascend

On August 22, 2023, we purchased $25.0 million of Ascend Preferred Stock from Ascend, a U.S.-based manufacturer and recycler of sustainable, engineered battery materials for electric vehicles.  The Ascend Preferred Stock provides for non-cumulative dividends when and if declared by Ascend's board of directors.  Each share is convertible, at any time, at our option, into shares of common stock of Ascend.  We account for our ownership interest in Ascend as an equity investment without a readily determinable fair value.  Absent an observable price change, it is not practicable to estimate the fair value of our investment in Ascend because of the lack of a quoted market price for our ownership interests.  Therefore, we use a measurement alternative other than fair value to account for our investment.  

13

10.PARTNERS' CAPITAL

Distributions

Distributions paid or declared during 2022 and 2023 were as follows:

Payment Date	Per Unit Cash Distribution		Total Cash Distribution
			(in thousands)
February 14, 2022	$	0.2500	$	32,750
May 13, 2022		0.3500		45,810
August 12, 2022		0.4000		52,338
November 14, 2022		0.5000		65,449
Total	$	1.5000	$	196,347
February 14, 2023	$	0.7000	$	91,938
May 15, 2023		0.7000		90,930
August 14, 2023		0.7000		90,899
November 14, 2023 (1)		0.7000		—
Total	$	2.8000	$	273,767

(1) On October 27, 2023, we declared this quarterly distribution payable on November 14, 2023 to all unitholders of record as of November 7, 2023.  

Unit Repurchase Program

In January 2023, the board of directors of MGP authorized a $93.5 million increase to the unit repurchase program, which had $6.5 million of available capacity as of December 31, 2022. As a result, we are authorized to repurchase up to a total of $100.0 million of ARLP common units. During the nine months ended September 30, 2023, we repurchased and retired 929,842 units at an average unit price of $20.90 for an aggregate purchase price of $19.4 million. Since inception of the unit repurchase program, we have repurchased and retired 6,390,446 units at an average unit price of $17.67 for an aggregate purchase price of $112.9 million.

14

Change in Partners' Capital

The following tables present the quarterly change in Partners' Capital for the nine months ended September 30, 2023 and 2022:

						Accumulated
	Number of	Limited		General		Other
	Limited Partner	Partners'		Partner's		Comprehensive		Noncontrolling		Total Partners'
	Units	Capital		Capital		Income (Loss)		Interest		Capital
	(in thousands, except unit data)
Balance at January 1, 2023	127,195,219	$	1,656,025	$	66,548	$	(41,054)	$	26,507	$	1,708,026
Comprehensive income:
Net income	—		189,801		1,384		—		1,493		192,678
Actuarially determined long-term liability adjustments	—		—		—		565		—		565
Total comprehensive loss											193,243
Settlement of deferred compensation plans	860,060		(9,320)		—		—		—		(9,320)
Purchase of units under unit repurchase program	(860,060)		(18,209)		—		—		—		(18,209)
Common unit-based compensation	—		2,830		—		—		—		2,830
Distributions on deferred common unit-based compensation	—		(2,901)		—		—		—		(2,901)
Distributions from consolidated company to affiliate noncontrolling interest	—		—		—		—		(2,288)		(2,288)
JC Resources acquisition - See Note 1	—		(7,251)		(64,999)		—		—		(72,250)
Cash retained by JC Resources in acquisition - See Note 1	—		—		(2,933)		—		—		(2,933)
Distributions to Partners	—		(89,037)		—		—		—		(89,037)
Balance at March 31, 2023	127,195,219		1,721,938		—		(40,489)		25,712		1,707,161
Comprehensive income:
Net income	—		169,790		—		—		1,515		171,305
Actuarially determined long-term liability adjustments	—		—		—		563		—		563
Total comprehensive income											171,868
Settlement of deferred compensation plans	—		(1,014)		—		—		—		(1,014)
Purchase of units under unit repurchase program	(69,782)		(1,223)		—		—		—		(1,223)
Common unit-based compensation	—		3,121		—		—		—		3,121
Distributions on deferred common unit-based compensation	—		(1,895)		—		—		—		(1,895)
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(2,226)		(2,226)
Distributions to Partners	—		(89,035)		—		—		—		(89,035)
Balance at June 30, 2023	127,125,437	$	1,801,682	$	—	$	(39,926)	$	25,001	$	1,786,757
Comprehensive income:
Net income	—		153,699		—		—		1,652		155,351
Actuarially determined long-term liability adjustments	—		—		—		561		—		561
Total comprehensive income	—		—				—		—		155,912
Common unit-based compensation	—		3,239		—		—		—		3,239
Distributions on deferred common unit-based compensation	—		(1,911)		—		—		—		(1,911)
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(2,081)		(2,081)
Distributions to Partners	—		(88,988)		—		—		—		(88,988)
Balance at September 30, 2023	127,125,437	$	1,867,721	$	—	$	(39,365)	$	24,572	$	1,852,928

15

						Accumulated
	Number of	Limited		General		Other
	Limited Partner	Partners'		Partner's		Comprehensive		Noncontrolling		Total Partners'
	Units	Capital		Capital *		Income (Loss)		Interest		Capital *
	(in thousands, except unit data)
Balance at January 1, 2022	127,195,219	$	1,279,183	$	68,075	$	(64,229)	$	11,115	$	1,294,144
Comprehensive income:
Net income	—		36,652		1,431		—		290		38,373
Actuarially determined long-term liability adjustments	—		—		—		790		—		790
Total comprehensive income											39,163
Common unit-based compensation	—		2,640		—		—		—		2,640
Distributions on deferred common unit-based compensation	—		(950)		—		—		—		(950)
Distributions from consolidated company to affiliate noncontrolling interest	—		—		—		—		(298)		(298)
Cash retained by JC Resources in acquisition - See Note 1	—		—		(1,590)		—		—		(1,590)
Distributions to Partners	—		(31,800)		—		—		—		(31,800)
Balance at March 31, 2022	127,195,219		1,285,725		67,916		(63,439)		11,107		1,301,309
Comprehensive income:
Net income	—		161,478		2,050		—		323		163,851
Actuarially determined long-term liability adjustments	—		—		—		794		—		794
Total comprehensive income											164,645
Common unit-based compensation	—		2,340		—		—		—		2,340
Distributions on deferred common unit-based compensation	—		(1,292)		—		—		—		(1,292)
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(325)		(325)
Cash retained by JC Resources in acquisition - See Note 1	—		—		(2,484)		—		—		(2,484)
Distributions to Partners	—		(44,518)		—		—		—		(44,518)
Balance at June 30, 2022	127,195,219	$	1,403,733	$	67,482	$	(62,645)	$	11,105	$	1,419,675
Comprehensive income:
Net income	—		164,607		3,101		—		364		168,072
Actuarially determined long-term liability adjustments	—		—		—		802		—		802
Total comprehensive income											168,874
Common unit-based compensation	—		2,677		—		—		—		2,677
Distributions on deferred common unit-based compensation	—		(1,461)		—		—		—		(1,461)
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(485)		(485)
Cash retained by JC Resources in acquisition - See Note 1	—		—		(3,578)		—		—		(3,578)
Distributions to Partners	—		(50,877)		—		—		—		(50,877)
Balance at September 30, 2022	127,195,219	$	1,518,679	$	67,005	$	(61,843)	$	10,984	$	1,534,825

* Recast as discussed in Note 1 – Organization and Presentation.  

16

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, 2023
Coal sales	$	342,744	$	206,379	$	—	$	—	$	—	$	549,123
Oil & gas royalties		—		—		34,125		—		—		34,125
Coal royalties		—		—		—		16,763		(16,763)		—
Transportation revenues		25,992		8,972		—		—		—		34,964
Other revenues		2,897		449		2,186		—		12,777		18,309
Total revenues	$	371,633	$	215,800	$	36,311	$	16,763	$	(3,986)	$	636,521
Three Months Ended September 30, 2022
Coal sales	$	314,271	$	236,292	$	—	$	—	$	—	$	550,563
Oil & gas royalties *		—		—		38,695		—		—		38,695
Coal royalties		—		—		—		16,708		(16,708)		—
Transportation revenues		19,508		9,040		—		—		—		28,548
Other revenues		1,455		392		2,918		—		9,890		14,655
Total revenues	$	335,234	$	245,724	$	41,613	$	16,708	$	(6,818)	$	632,461
Nine Months Ended September 30, 2023
Coal sales	$	1,011,467	$	676,771	$	—	$	—	$	—	$	1,688,238
Oil & gas royalties		—		—		101,709		—		—		101,709
Coal royalties		—		—		—		48,843		(48,843)		—
Transportation revenues		68,498		27,231		—		—		—		95,729
Other revenues		7,466		1,299		3,551		—		43,287		55,603
Total revenues	$	1,087,431	$	705,301	$	105,260	$	48,843	$	(5,556)	$	1,941,279
Nine Months Ended September 30, 2022
Coal sales	$	858,565	$	612,165	$	—	$	—	$	—	$	1,470,730
Oil & gas royalties *		—		—		111,378		—		—		111,378
Coal royalties		—		—		—		46,400		(46,400)		—
Transportation revenues		59,848		33,457		—		—		—		93,305
Other revenues		5,014		1,083		3,711		—		30,540		40,348
Total revenues	$	923,427	$	646,705	$	115,089	$	46,400	$	(15,860)	$	1,715,761

* Recast as discussed in Note 1 – Organization and Presentation.

17

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, 2023 and disaggregated by segment and contract duration.

							2026 and
	2023		2024		2025		Thereafter		Total
	(in thousands)
Illinois Basin Coal Operations coal revenues	$	424,747	$	1,123,629	$	469,601	$	351,600	$	2,369,577
Appalachia Coal Operations coal revenues		234,015		567,220		325,425		1,600		1,128,260
Total coal revenues (1)	$	658,762	$	1,690,849	$	795,026	$	353,200	$	3,497,837

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

12.EARNINGS PER LIMITED PARTNER UNIT

We utilize the two-class method in calculating basic and diluted earnings per limited partner unit ("EPU").  Subsequent to the JC Resources Acquisition, which is discussed in more detail in Note 1 – Organization and Presentation, net income attributable to ARLP is allocated to limited partners and participating securities with nonforfeitable distributions or distribution equivalents, while net losses attributable to ARLP are allocated only to limited partners but not to participating securities.  Prior to the JC Resources Acquisition, in addition to limited partners and participating securities allocations, amounts are also allocated to our general partner for historical earnings from the mineral interests acquired in the JC Resources Acquisition.  

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").

18

The following is a reconciliation of net income 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, 2023 and 2022:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022 (1)		2023		2022 (1)
	(in thousands, except per unit data)
Net income attributable to ARLP	$	153,699	$	167,708	$	514,674	$	369,319
Adjustment:
General partner's interest in net income attributable to ARLP		—		(3,101)		(1,384)		(6,582)
Limited partners' interest in net income attributable to ARLP		153,699		164,607		513,290		362,737
Less:
Distributions to participating securities		(2,414)		(2,180)		(7,242)		(5,452)
Undistributed earnings attributable to participating securities		(1,652)		(3,275)		(6,596)		(6,504)
Net income attributable to ARLP available to limited partners	$	149,633	$	159,152	$	499,452	$	350,781
Weighted-average limited partner units outstanding – basic and diluted		127,125		127,195		127,199		127,195
Earnings per limited partner unit - basic and diluted (2)	$	1.18	$	1.25	$	3.93	$	2.76

(1) Recast as discussed in Note 1 – Organization and Presentation.

(2) 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 2,759 and 2,878 for the three and nine months ended September 30, 2023, respectively, and 3,754 and 3,431 for the three and nine months ended September 30, 2022, 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,
	2023		2022		2023		2022
	(in thousands)
Beginning balance	$	51,108	$	47,221	$	49,452	$	53,448
Changes in accruals		3,001		2,918		9,071		7,464
Payments		(3,503)		(2,856)		(10,008)		(8,938)
Interest accretion		551		287		1,652		861
Valuation loss (gain) (1)		—		—		990		(5,265)
Ending balance	$	51,157	$	47,570	$	51,157	$	47,570

(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 loss in 2023 is due to adverse claims development.  The valuation gain in 2022 is due to an increase in the discount rate from 2.41% on December 31, 2021 to 4.22% on June 30, 2022.

19

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, 2023 are $4.1 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,
	2023		2022		2023		2022
	(in thousands)
Service cost	$	678	$	949	$	2,022	$	2,850
Interest cost (1)		1,237		747		3,713		2,243
Net amortization (1)		345		260		1,036		779
Net periodic benefit cost	$	2,260	$	1,956	$	6,771	$	5,872

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

14.COMMON UNIT-BASED COMPENSATION PLANS

Long-Term Incentive Plan

A summary of non-vested LTIP grants as of and for the nine months ended September 30, 2023 is as follows:

	Number of units	Weighted average grant date fair value per unit		Intrinsic value
				(in thousands)
Non-vested grants at January 1, 2023	3,697,133	$	7.40		75,126
Granted (1)	447,225		21.54
Vested (2)	(1,291,330)		5.02
Forfeited	(145,584)		6.86
Non-vested grants at September 30, 2023	2,707,444		10.90		60,999

(1) The restricted units granted during 2023 have certain minimum-value guarantees per unit, regardless of whether or not the awards vest.

(2) During the nine months ended September 30, 2023, we issued 860,060 unrestricted common units to the LTIP participants.  The remaining vested units were settled in cash to satisfy tax withholding obligations of the LTIP participants.

LTIP expense for grants of restricted units was $2.7 million and $2.4 million for the three months ended September 30, 2023 and 2022, respectively, and $7.7 million and $6.8 million for the nine months ended September 30, 2023 and 2022, respectively. The total obligation associated with LTIP grants of restricted units as of September 30, 2023 was $16.8 million and is included in the partners' capital Limited partners-common unitholders line item in our condensed consolidated balance sheets.  As of September 30, 2023, there was $12.7 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 0.8 years.

20

Supplemental Executive Retirement Plan and Directors' Deferred Compensation Plan

A summary of SERP and Directors' Deferred Compensation Plan activity as of and for the nine months ended September 30, 2023 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, 2023	742,540	$	20.28	$	15,088
Granted	75,648		19.75
Settled (1)	(49,331)		20.27
Phantom units outstanding as of September 30, 2023	768,857		20.36		17,322

(1) During the nine months ended September 30, 2023, we purchased 27,576 ARLP common units on the open market to settle the account of a participant under the SERP.  Units purchased and delivered to the participant were net of units settled in cash to satisfy tax withholding obligations.

Total SERP and Directors' Deferred Compensation Plan expense was $0.6 million and $0.4 million for the three months ended September 30, 2023 and 2022, respectively, and $1.8 million and $0.9 million for the nine months ended September 30, 2023 and 2022, respectively. As of September 30, 2023, the total obligation associated with the SERP and Directors' Deferred Compensation Plan was $15.7 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,
	2023		2022		2023		2022
	(in thousands)
Interest cost	$	1,294	$	940	$	3,885	$	2,808
Expected return on plan assets		(1,553)		(1,654)		(4,668)		(4,983)
Amortization of prior service cost		47		47		140		140
Amortization of net loss		169		495		513		1,467
Net periodic benefit credit (1)	$	(43)	$	(172)	$	(130)	$	(568)

(1) Net periodic benefit credit for the Pension Plan is included in the Other income (expense) line item within our condensed consolidated statements of income.

As a result of certain pension plan relief provided by the American Rescue Plan Act enacted in March 2021, we do not expect to make contributions to the Pension Plan during 2023.

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, metallurgical and industrial users as well as royalty income from oil & gas mineral interests. In addition, we continue to position ourselves as a reliable energy partner for the future as we pursue opportunities that support the advancement of energy and related infrastructure. 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. Our two coal operations reportable segments correspond to major coal producing regions in the eastern

21

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 mineral reserves and resources owned or leased by Alliance Resource Properties, which are either (a) leased to our mining complexes or (b) near our coal mining operations but not yet leased.

The Illinois Basin Coal Operations reportable segment includes (a) the Gibson County Coal mining complex, (b) the Warrior mining complex, (c) the River View mining complex and (d) the Hamilton mining complex. The segment also includes our Mt. Vernon Transfer Terminal, LLC ("Mt. Vernon") coal loading terminal in Indiana which operates on the Ohio River, Mid-America Carbonates, LLC and other support services, and our non-operating mining complexes.      

The Appalachia Coal Operations reportable segment includes (a) the Mettiki mining complex, (b) the Tunnel Ridge mining complex and (c) the MC Mining mining complex.

The 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 III (Note 9 – Equity Investments) and Cavalier Minerals.

The Coal Royalties reportable segment includes coal mineral reserves and resources owned or leased by Alliance Resource Properties that are (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. Approximately 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, its subsidiaries, and Alliance Design Group, LLC (collectively referred to as the "Matrix Group"), our investments in Francis, Infinitum, NGP ET IV, and Ascend (see Note 9 – Equity Investments), Wildcat Insurance, which assists the ARLP Partnership with its insurance requirements, AROP Funding and Alliance Finance (both discussed in Note 6 – 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.

22

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, 2023
Revenues - Outside	$	371,633	$	215,800	$	36,311	$	—	$	12,777	$	636,521
Revenues - Intercompany		—		—		—		16,763		(16,763)		—
Total revenues (2)		371,633		215,800		36,311		16,763		(3,986)		636,521
Segment Adjusted EBITDA Expense (3)		213,209		131,997		3,873		6,851		(5,524)		350,406
Segment Adjusted EBITDA (4)		132,428		74,832		31,366		9,912		(881)		247,657
Capital expenditures (5)		59,833		30,304		—		—		20,202		110,339
Three Months Ended September 30, 2022
Revenues - Outside (1)	$	335,234	$	245,724	$	41,613	$	—	$	9,890	$	632,461
Revenues - Intercompany		—		—		—		16,708		(16,708)		—
Total revenues (2)		335,234		245,724		41,613		16,708		(6,818)		632,461
Segment Adjusted EBITDA Expense (1) (3)		194,967		134,672		3,926		5,545		(8,609)		330,501
Segment Adjusted EBITDA (1) (4)		120,760		102,012		39,429		11,163		1,792		275,156
Capital expenditures		39,529		17,780		—		40,033		1,962		99,304
Nine Months Ended September 30, 2023
Revenues - Outside	$	1,087,431	$	705,301	$	105,260	$	—	$	43,287	$	1,941,279
Revenues - Intercompany		—		—		—		48,843		(48,843)		—
Total revenues (2)		1,087,431		705,301		105,260		48,843		(5,556)		1,941,279
Segment Adjusted EBITDA Expense (3)		634,944		377,115		11,859		17,836		(13,618)		1,028,136
Segment Adjusted EBITDA (4)		383,987		300,955		90,461		31,007		2,560		808,970
Total assets		882,943		459,742		767,415		319,930		384,011		2,814,041
Capital expenditures (5)		179,284		94,119		—		400		21,553		295,356
Nine Months Ended September 30, 2022
Revenues - Outside (1)	$	923,427	$	646,705	$	115,089	$	—	$	30,540	$	1,715,761
Revenues - Intercompany		—		—		—		46,400		(46,400)		—
Total revenues (2)		923,427		646,705		115,089		46,400		(15,860)		1,715,761
Segment Adjusted EBITDA Expense (1) (3)		567,253		335,756		10,785		15,762		(21,177)		908,379
Segment Adjusted EBITDA (1) (4)		296,327		277,492		107,902		30,638		5,317		717,676
Total assets (1)		731,441		428,000		756,879		325,498		329,568		2,571,386
Capital expenditures		111,419		58,616		—		40,033		11,218		221,286

(1) Recast for the JC Resources Acquisition as discussed in Note 1 – Organization and Presentation.

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

(3) Segment Adjusted EBITDA Expense includes operating expenses, coal purchases, if applicable, 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.  

23

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,
	2023		2022		2023		2022
	(in thousands)
Operating expenses (excluding depreciation, depletion and amortization)	$	339,099	$	330,694	$	1,012,224	$	909,567
Outside coal purchases		11,530		—		15,739		151
Other expense (income)		(223)		(193)		173		(1,339)
Segment Adjusted EBITDA Expense	$	350,406	$	330,501	$	1,028,136	$	908,379

(4) Segment Adjusted EBITDA is defined as net income attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization, and general and administrative expenses.  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,
	2023		2022		2023		2022
	(in thousands)
Net income	$	155,351	$	168,072	$	519,334	$	370,296
Noncontrolling interest		(1,652)		(364)		(4,660)		(977)
Net income attributable to ARLP	$	153,699	$	167,708	$	514,674	$	369,319
General and administrative		20,097		21,360		61,312		62,462
Depreciation, depletion and amortization		65,393		70,669		199,582		202,499
Interest expense, net		5,067		8,819		21,761		27,750
Income tax expense		3,401		6,600		11,641		55,646
Consolidated Segment Adjusted EBITDA	$	247,657	$	275,156	$	808,970	$	717,676

(5) Capital expenditures for the three and nine months ended September 30, 2023 exclude $10.0 million and $13.9 million, respectively, paid towards the oil & gas reserve acquisitions.  Capital expenditures for the nine months ended September 30, 2023 also exclude the $72.3 million paid for the JC Resources Acquisition (See Note 2 – Acquisitions).

24

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, an indirect wholly owned subsidiary of ARLP.

● References to "Alliance Minerals" mean Alliance Minerals, LLC, an indirect wholly owned subsidiary of ARLP.

● References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, an indirect wholly owned subsidiary of ARLP.

Summary

We are a diversified natural resource company that generates operating and royalty income from the production and marketing of coal to major domestic utilities, industrial users and international customers, as well as royalty income from oil & gas mineral interests located in strategic producing regions across the United States.  In addition, we continue to position ourselves as a reliable energy partner for the future as we pursue opportunities that support the advancement of energy and related infrastructure.  We intend to pursue strategic investments that leverage our core competencies and relationships with electric utilities, industrial customers, and federal and state governments.

We are currently the largest coal producer in the eastern United States with seven operating underground mining complexes near many of the major eastern utility generating plants and on major coal hauling railroads in Illinois, Indiana, Kentucky, Maryland, Pennsylvania, and West Virginia, as well as a coal-loading terminal in Indiana on the Ohio River. Two of our mines also have loading facilities located on the Ohio River.

In addition to our mining operations, Alliance Resource Properties owns or leases substantially all of our measured, indicated and inferred coal mineral resources and the majority of our proved and probable coal mineral reserves in the Illinois and Appalachia Basins that are (a) leased to our internal mining complexes or (b) near our coal mining operations but not yet leased.

We currently own oil & gas mineral interests in approximately 65,000 net royalty acres in premier oil & gas producing regions of the United States, primarily in the Permian (Delaware and Midland), Anadarko (SCOOP/STACK), and Williston (Bakken) basins, providing us with diversified exposure to industry-leading operators consistent with our general strategy to grow our oil & gas mineral interest business.

We have invested in energy and infrastructure opportunities including our investments in Francis Renewable Energy, LLC ("Francis"), Infinitum Electric, Inc. ("Infinitum"), NGP Energy Transition, L.P. ("NGP ET IV"), and Ascend Elements, Inc. ("Ascend") which are in the businesses of, respectively, electric vehicle charging stations, electric motor manufacturing, private equity investments in renewable energy, the electrification of our economy or the efficient use of energy, and the manufacturing and recycling of sustainable, engineered battery materials for electric vehicles.  

On January 27, 2023, we entered into a one-year collaborative agreement with a third party effective January 1, 2023, committing up to $35.0 million for the acquisition of oil & gas mineral interests in the Midland and Delaware basins (the "Acquisition Agreement").

25

On February 22, 2023, we acquired mineral interests in approximately 2,682 oil & gas net royalty acres in the Delaware Basin from JC Resources, LP ("JC Resources"), a related-party entity owned by Mr. Craft (the "JC Resources Acquisition").

For more information about the Acquisition Agreement and the JC Resources Acquisition, please read "Item 1. Financial Statements (Unaudited)—Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q.

On August 22, 2023, we purchased $25.0 million of Series D Preferred Stock from Ascend, a U.S. based manufacturer and recycler of sustainable, engineered battery materials for electric vehicles.

On September 8, 2023, we purchased $24.6 million of Series E Preferred Stock from Infinitum, a U.S. based startup developer and manufacturer of electric motors featuring printed circuit board stators.

For more information about the Ascend and Infinitum investments, please read "Item 1. Financial Statements (Unaudited)—Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q.

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. Our Oil & Gas Royalties reportable segment includes our oil & gas mineral interests. Our Coal Royalties reportable segment includes coal mineral reserves and resources owned or leased by Alliance Resource Properties, which are either (a) leased to our mining complexes or (b) near our coal mining operations but not yet leased.

● Illinois Basin Coal Operations reportable segment includes (a) the Gibson County Coal mining complex, (b) the Warrior mining complex, (c) the River View mining complex and (d) the Hamilton mining complex. The segment also includes our Mt. Vernon coal-loading terminal on the Ohio River in Indiana, Mid-America Carbonates, LLC and other support services, and our non-operating mining complexes.

● Appalachia Coal Operations reportable segment includes (a) the Mettiki mining complex, (b) the Tunnel Ridge mining complex and (c) the MC Mining mining complex.

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

● Coal Royalties reportable segment includes coal mineral reserves and resources owned or leased by Alliance Resource Properties. Approximately 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 ("Matrix Design"), its subsidiaries and Alliance Design Group, LLC, our investments in Francis, Infinitum, NGP ET IV, and Ascend, Wildcat Insurance, LLC, which assists the ARLP Partnership with its insurance requirements, AROP Funding, LLC ("AROP Funding") and Alliance Resource Finance Corporation ("Alliance Finance"), 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 9 – Equity Investments" and —Note 6 – Long-Term Debt" of this Quarterly Report on Form 10-Q for more information on our investments in Francis, Infinitum, Ascend, and NGP ET IV as well as AROP Funding and Alliance Finance.

26

Three Months Ended September 30, 2023 Compared to Three Months Ended September 30, 2022

	Three Months Ended September 30,
	2023		2022 (1)		2023		2022 (1)
	(in thousands)				(per ton / per BOE sold)
Coal - Tons sold		8,456		9,185		N/A		N/A
Coal - Tons produced		8,356		8,988		N/A		N/A
Coal - Coal sales	$	549,123	$	550,563	$	64.94	$	59.94
Coal - Segment Adjusted EBITDA Expense (2) (3)	$	348,290	$	332,503	$	41.19	$	36.20
Oil & Gas Royalties - BOE sold		772		602		N/A		N/A
Oil & Gas Royalties - Royalties (4)	$	34,125	$	38,695	$	44.19	$	64.27
Coal Royalties - Tons sold		4,993		5,654		N/A		N/A
Coal Royalties - Intercompany royalties	$	16,763	$	16,708	$	3.36	$	2.96

(1) Recast for the JC Resources Acquisition.  For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.

(2) 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 GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"

(3) Beginning in 2023, we redefined Coal - Segment Adjusted EBITDA Expense to reflect the activity of Alliance Coal, which is the holding company for our coal mining operations.  We have retrospectively adjusted Coal - Segment Adjusted EBITDA Expense in prior periods to be on the same basis.

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

Total Revenues.  Total revenues for the three months ended September 30, 2023 ("2023 Quarter") increased slightly to $636.5 million compared to $632.5 million for the quarter ended September 30, 2022 (the "2022 Quarter") primarily as a result of higher transportation and other revenues, partially offset by lower oil & gas royalties.  

Total operating expenses.  Total operating expenses increased to $471.1 million in the 2023 Quarter, compared to $451.3 million in the 2022 Quarter, due primarily to the sale of higher cost purchased coal and increased per ton costs on certain expense items discussed in more detail below.  

Net income attributable to ARLP.  Net income attributable to ARLP for 2023 Quarter was $153.7 million, or $1.18 per basic and diluted limited partner unit, compared to $167.7 million, or $1.25 per basic and diluted limited partner unit, for the 2022 Quarter as a result of increased total operating expenses and equity method investment losses in the 2023 Quarter, partially offset by increased revenues, higher interest income and lower income tax expense.

Coal sales.  Coal sales remained consistent at $549.1 million for the 2023 Quarter compared to $550.6 million for the 2022 Quarter.  The slight decrease was attributable to lower tons sold, which reduced coal sales by $43.7 million, partially offset by the benefit of higher average coal sales prices, which contributed $42.3 million in additional coal sales.  Tons sold decreased by 7.9% primarily due to decreased sales volumes in Appalachia as a result of lock outages, customer plant maintenance, reduced operating units at MC Mining and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation. Improved domestic pricing, partially offset by lower export price realizations, drove coal sales prices higher by 8.3% in the 2023 Quarter to $64.94 per ton sold, compared to $59.94 per ton sold during the 2022 Quarter.  

Coal - Segment Adjusted EBITDA Expense.  Segment Adjusted EBITDA Expense for our coal operations increased 4.7% to $348.3 million, as a result of higher per ton costs.  Segment Adjusted EBITDA Expense per ton sold for our coal operations increased 13.8% to $41.19 per ton sold in the 2023 Quarter compared to $36.20 per ton in the 2022 Quarter, primarily due to lower volumes and certain cost increases, which are discussed below by category:

● Labor and benefit expenses per ton produced, excluding workers' compensation, increased 17.5% to $12.37 per ton in the 2023 Quarter from $10.53 per ton in the 2022 Quarter.  The increase of $1.84 per ton was primarily due to higher direct labor costs at several mines.

27

● Material and supplies expenses per ton produced increased 5.7% to $13.93 per ton in the 2023 Quarter from $13.18 per ton in the 2022 Quarter.  The increase of $0.75 per ton produced primarily reflects increases of $0.54 per ton for roof support, $0.26 per ton for ventilation related expenses and $0.17 per ton for power and fuel.  These increases were partially offset by decreases of $0.26 per ton in longwall subsidence expense, $0.17 per ton for outside expenses and $0.16 per ton for contract labor used in the mining process.

● Maintenance expenses per ton produced increased 35.4% to $4.86 per ton in the 2023 Quarter from $3.59 per ton in the 2022 Quarter.  The increase of $1.27 per ton produced was primarily as a result of reduced production volumes and inflationary cost pressures.

● Production taxes and royalty expenses per ton incurred as a percentage of coal sales prices increased $0.83 per produced ton sold in the 2023 Quarter compared to the 2022 Quarter primarily as a result of higher price realizations, increased excise taxes per ton resulting from a reduced mix of export shipments, higher federal black lung excise tax as a result of the tax rate increasing effective October 1, 2022 and an unfavorable mix of tons sold mined in states with severance taxes.

● We had outside coal purchases of $11.5 million to meet contractual commitments in the 2023 Quarter as a result of unique geological conditions that delayed development of a new district at our Mettiki longwall operation compared to no sales of outside coal purchases in the 2022 Quarter. Thus, costs per ton in the 2023 Quarter increased as our cost of outside coal purchases are generally higher on a per ton basis than our produced coal.

Oil & gas royalties.  Oil & gas royalty revenues decreased to $34.1 million in the 2023 Quarter compared to $38.7 million for the 2022 Quarter.  The decrease of $4.6 million was primarily due to lower average sales price per BOE, which decreased by 31.2%, partially offset by higher BOE volumes.

Other revenues.  Other revenues principally comprised Matrix Design sales, Mt. Vernon transloading revenues, oil & gas lease bonus revenues and other miscellaneous sales and revenue activities.  Other revenues increased to $18.3 million in the 2023 Quarter from $14.7 million in the 2022 Quarter.  The increase of $3.6 million was primarily due to increased transloading revenues and sales of mining technology products by our Matrix Design subsidiary as well as higher revenues from other miscellaneous sales activities.

Depreciation, depletion and amortization.  Depreciation, depletion and amortization expense decreased to $65.4 million for the 2023 Quarter compared to $70.7 million for the 2022 Quarter primarily as a result of reduced coal sales volumes.

Equity method investment income (loss).  We had an equity method investment loss of $1.8 million in the 2023 Quarter compared to equity method investment income of $2.1 million in the 2022 Quarter.  The change was primarily due to losses attributable to our investment in Francis, partially offset by income from our AllDale III investment.

Income tax expense.  Income tax expense decreased to $3.4 million for the 2023 Quarter compared to $6.6 million for the 2022 Quarter primarily as a result of reduced income from our oil & gas mineral interests.

Transportation revenues and expenses.  Transportation revenues and expenses were $35.0 million and $28.5 million for the 2023 and 2022 Quarters, respectively.  The increase of $6.5 million was primarily attributable to increased third-party transportation rates in the 2023 Quarter, partially offset by reduced coal shipments 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.

28

Segment Adjusted EBITDA.  Our 2023 Quarter Segment Adjusted EBITDA decreased $27.5 million to $247.7 million from the 2022 Quarter Segment Adjusted EBITDA of $275.2 million.  

	Three Months Ended
	September 30,
	2023		2022 (1)		Increase (Decrease)
	(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations	$	132,428	$	120,760	$	11,668	9.7	%
Appalachia Coal Operations		74,832		102,012		(27,180)	(26.6)	%
Oil & Gas Royalties		31,366		39,429		(8,063)	(20.4)	%
Coal Royalties		9,912		11,163		(1,251)	(11.2)	%
Other, Corporate and Elimination (2)		(881)		1,792		(2,673)	(149.2)	%
Total Segment Adjusted EBITDA (3)	$	247,657	$	275,156	$	(27,499)	(10.0)	%
Coal - Tons sold
Illinois Basin Coal Operations		6,049		6,109		(60)	(1.0)	%
Appalachia Coal Operations		2,407		3,076		(669)	(21.7)	%
Total tons sold		8,456		9,185		(729)	(7.9)	%
Coal sales
Illinois Basin Coal Operations	$	342,744	$	314,271	$	28,473	9.1	%
Appalachia Coal Operations		206,379		236,292		(29,913)	(12.7)	%
Total coal sales	$	549,123	$	550,563	$	(1,440)	(0.3)	%
Other revenues
Illinois Basin Coal Operations	$	2,897	$	1,455	$	1,442	99.1	%
Appalachia Coal Operations		449		392		57	14.5	%
Oil & Gas Royalties		2,186		2,918		(732)	(25.1)	%
Other, Corporate and Elimination		12,777		9,890		2,887	29.2	%
Total other revenues	$	18,309	$	14,655	$	3,654	24.9	%
Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations	$	213,209	$	194,967	$	18,242	9.4	%
Appalachia Coal Operations		131,997		134,672		(2,675)	(2.0)	%
Oil & Gas Royalties		3,873		3,926		(53)	(1.3)	%
Coal Royalties		6,851		5,545		1,306	23.6	%
Other, Corporate and Elimination (2)		(5,524)		(8,609)		3,085	35.8	%
Total Segment Adjusted EBITDA Expense (3)	$	350,406	$	330,501	$	19,905	6.0	%
Oil & Gas Royalties
Volume - BOE (4)		772		602		170	28.2	%
Oil & gas royalties	$	34,125	$	38,695	$	(4,570)	(11.8)	%
Coal Royalties
Volume - Tons sold (5)		4,993		5,654		(661)	(11.7)	%
Intercompany coal royalties	$	16,763	$	16,708	$	55	0.3	%

(1) Recast for the JC Resources Acquisition.  For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.

(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.

(3) For definitions of Segment Adjusted EBITDA and Segment Adjusted EBITDA Expense and related reconciliations to their respective comparable GAAP financial measures, please see below under "—Reconciliation of GAAP 'net

29

income' to non-GAAP 'Segment Adjusted EBITDA' and reconciliation of GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"

(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 that were produced from coal reserves leased from our Coal Royalties Segment.

Illinois Basin Coal Operations – Segment Adjusted EBITDA increased 9.7% to $132.4 million in the 2023 Quarter from $120.8 million in the 2022 Quarter.  The increase of $11.6 million was primarily attributable to higher coal sales, which increased 9.1% to $342.7 million in the 2023 Quarter from $314.3 million in the 2022 Quarter, partially offset by increased operating expenses. The increase in coal sales reflects higher coal sales price realizations of $56.66 per ton sold in the 2023 Quarter compared to $51.44 per ton sold in the 2022 Quarter due to improved domestic pricing, partially offset by lower export price realizations. Segment Adjusted EBITDA Expense increased 9.4% to $213.2 million in the 2023 Quarter from $195.0 million in the 2022 Quarter primarily as a result of higher operating expenses per ton.  Segment Adjusted EBITDA Expense per ton increased by 10.5% compared to the 2022 Quarter resulting from increased sales-related expenses due to higher price realizations and higher labor-related, roof support and maintenance costs due to days lost by a sizable roof fall in July and a longwall move in August at our Hamilton mine.

Appalachia Coal Operations – Segment Adjusted EBITDA decreased 26.6% to $74.8 million for the 2023 Quarter from $102.0 million in the 2022 Quarter.  The decrease of $27.2 million was primarily attributable to lower coal sales, which decreased 12.7% to $206.4 million in the 2023 Quarter from $236.3 million in the 2022 Quarter.  Tons sold decreased by 21.7% compared to the 2022 Quarter as a result of reduced volumes across the region primarily from lock outages, customer plant maintenance, reduced operating units at MC Mining and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation.  Improved domestic pricing, partially offset by lower export price realizations, drove coal sales prices higher by 11.6% as compared to the 2022 Quarter.  Segment Adjusted EBITDA Expense decreased 2.0% to $132.0 million in the 2023 Quarter from $134.7 million in the 2022 Quarter due to reduced sales volumes, partially offset by higher per ton operating expenses.  Segment Adjusted EBITDA Expense per ton increased by 25.3% compared to the 2022 Quarter due primarily to lower production volumes, purchased coal and increased labor-related, roof support, maintenance and selling expenses per ton.

Oil & Gas Royalties – Segment Adjusted EBITDA decreased to $31.4 million in the 2023 Quarter compared to $39.4 million in the 2022 Quarter.  The decrease primarily resulted from lower price realizations, which decreased by 31.2%, partially offset by record oil & gas volumes, which increased 28.2% to 772 MBOE sold in the 2023 Quarter.  Higher volumes during the 2023 Quarter resulted from increased drilling and completion activities on our interests and the acquisition of additional oil & gas mineral interests.

Coal Royalties – Segment Adjusted EBITDA was $9.9 million for the 2023 Quarter, representing a decrease of $1.3 million compared to the 2022 Quarter, as a result of lower royalty tons sold and increased selling expenses, partially offset by higher average royalty rates per ton received from the Partnership's mining subsidiaries.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

	Nine Months Ended September 30,
	2023		2022 (1)		2023		2022 (1)
	(in thousands)				(per ton / per BOE sold)
Coal - Tons sold		25,829		26,280		N/A		N/A
Coal - Tons produced		26,997		27,044		N/A		N/A
Coal - Coal sales	$	1,688,238	$	1,470,730	$	65.36	$	55.96
Coal - Segment Adjusted EBITDA Expense (2) (3)	$	1,021,191	$	907,969	$	39.54	$	34.55
Oil & Gas Royalties - BOE sold		2,296		1,690		N/A		N/A
Oil & Gas Royalties - Royalties (4)	$	101,709	$	111,378	$	44.29	$	65.92
Coal Royalties - Tons sold		15,168		16,475		N/A		N/A
Coal Royalties - Intercompany royalties	$	48,843	$	46,400	$	3.22	$	2.82

(1) Recast for the JC Resources Acquisition.  For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.

30

(2) 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 GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"

(3) Beginning in 2023, we redefined Coal - Segment Adjusted EBITDA Expense to reflect the activity of Alliance Coal, which is the holding company for our coal mining operations.  We have retrospectively adjusted Coal - Segment Adjusted EBITDA Expense in prior periods to be on the same basis.

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

Total Revenues.  Total revenues for the nine months ended September 30, 2023 ("2023 Period") increased 13.1% to $1.94 billion compared to $1.72 billion for the nine months ended September 30, 2022 ("2022 Period") primarily as a result of higher coal sales. Coal sales prices and coal sales revenues during the 2023 Period were higher by 16.8% and 14.8%, respectively, compared to the 2022 Period.

Total operating expenses.  Total operating expenses increased to $1.38 billion in the 2023 Period, compared to $1.27 billion in the 2022 Period, due primarily to higher per ton costs on certain expense items discussed in more detail below and sale of higher cost purchased coal.

Net income attributable to ARLP.  Increased revenues and lower income tax expense were partially offset by higher total operating expenses in the 2023 Period, resulting in higher net income attributable to ARLP for the 2023 Period of $514.7 million, or $3.93 per basic and diluted limited partner unit, compared to $369.3 million, or $2.76 per basic and diluted limited partner unit, for the 2022 Period.  

Coal sales.  Coal sales increased $217.5 million to $1.69 billion for the 2023 Period compared to $1.47 billion for the 2022 Period.  The increase reflects the benefit of higher average coal sales prices, which contributed $242.7 million in additional coal sales, partially offset by lower tons sold, which reduced coal sales by $25.2 million.  Higher price realizations in domestic markets drove coal sales prices higher by 16.8% in the 2023 Period to $65.36 per ton sold, compared to $55.96 per ton sold during the 2022 Period.  

Coal - Segment Adjusted EBITDA Expense.  Segment Adjusted EBITDA Expense for our coal operations increased 12.5% to $1.02 billion, as a result of higher per ton costs.  On a per ton basis, Segment Adjusted EBITDA Expense for our coal operations increased 14.4% to $39.54 per ton sold in the 2023 Period compared to $34.55 per ton in the 2022 Period, primarily due to certain cost increases, which are discussed below by category:

● Labor and benefit expenses per ton produced, excluding workers' compensation, increased 16.7% to $11.81 per ton in the 2023 Period from $10.12 per ton in the 2022 Period.  The increase of $1.69 per ton was primarily due to higher incentive benefits and direct labor costs at several mines.

● Workers' compensation expenses per ton produced increased to $0.56 per ton in the 2023 Period from $0.27 per ton in the 2022 Period.  The increase of $0.29 per ton produced primarily reflects a favorable mid-year workers' compensation accrual adjustment in the 2022 Period due to an increase in the discount rate.  

● Material and supplies expenses per ton produced increased 3.7% to $13.57 per ton in the 2023 Period from $13.08 per ton in the 2022 Period.  The increase of $0.49 per ton produced primarily reflects increases of $0.26 per ton for ventilation related expenses, $0.14 per ton for various preparation plant expenses and $0.14 per ton for power and fuel, partially offset by a decrease of $0.15 per ton for roof support.

● Maintenance expenses per ton produced increased 27.7% to $4.43 per ton in the 2023 Period from $3.47 per ton in the 2022 Period.  The increase of $0.96 per ton produced was primarily as a result of inflationary cost pressures.

● Production taxes and royalty expenses per ton incurred as a percentage of coal sales prices and volumes increased $0.94 per produced ton sold in the 2023 Period compared to the 2022 Period primarily as a result of higher price realizations, increased excise taxes per ton resulting from a reduced mix of export shipments and higher federal black lung excise tax as a result of the tax rate increasing effective October 1, 2022, partially offset by a favorable mix of tons sold mined in states without severance taxes.

31

● Outside coal purchases increased $15.6 million in the 2023 Period as a result of increased sales of purchased coal to meet contractual commitments at our Mettiki longwall operation which experienced unique geological conditions that delayed development of a new district.  Purchased coal generally costs more on a per ton basis than our produced coal.

Oil & gas royalties.  Oil & gas royalty revenues decreased to $101.7 million in the 2023 Period compared to $111.4 million for the 2022 Period.  The decrease of $9.7 million was primarily due to lower average sales price per BOE, which decreased by 32.8%, partially offset by higher BOE volumes.

Other revenues.  Other revenues principally comprised Matrix Design sales, Mt. Vernon transloading revenues, oil & gas lease bonus revenues and other miscellaneous sales and revenue activities.  Other revenues increased to $55.6 million in the 2023 Period from $40.3 million in the 2022 Period.  The increase of $15.3 million was primarily due to increased transloading revenues and sales of mining technology products by our Matrix Design subsidiary as well as higher revenues from other miscellaneous sales activities.

Income tax expense.  Income tax expense decreased to $11.6 million for the 2023 Period compared to $55.6 million for the 2022 Period primarily as a result of our recognition of a one-time non-cash income tax charge of $37.3 million during the 2022 Period when Alliance Minerals elected to be treated as a taxable entity for federal and state income tax purposes.

32

Segment Adjusted EBITDA.  Our 2023 Period Segment Adjusted EBITDA increased 12.7% to $809.0 million from the 2022 Period Segment Adjusted EBITDA of $717.7 million.  

	Nine Months Ended
	September 30,
	2023		2022 (1)		Increase (Decrease)
	(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations	$	383,987	$	296,327	$	87,660	29.6	%
Appalachia Coal Operations		300,955		277,492		23,463	8.5	%
Oil & Gas Royalties		90,461		107,902		(17,441)	(16.2)	%
Coal Royalties		31,007		30,638		369	1.2	%
Other, Corporate and Elimination (2)		2,560		5,317		(2,757)	(51.9)	%
Total Segment Adjusted EBITDA (3)	$	808,970	$	717,676	$	91,294	12.7	%
Coal - Tons sold
Illinois Basin Coal Operations		18,305		17,822		483	2.7	%
Appalachia Coal Operations		7,524		8,458		(934)	(11.0)	%
Total tons sold		25,829		26,280		(451)	(1.7)	%
Coal sales
Illinois Basin Coal Operations	$	1,011,467	$	858,565	$	152,902	17.8	%
Appalachia Coal Operations		676,771		612,165		64,606	10.6	%
Total coal sales	$	1,688,238	$	1,470,730	$	217,508	14.8	%
Other revenues
Illinois Basin Coal Operations	$	7,466	$	5,014	$	2,452	48.9	%
Appalachia Coal Operations		1,299		1,083		216	19.9	%
Oil & Gas Royalties		3,551		3,711		(160)	(4.3)	%
Other, Corporate and Elimination		43,287		30,540		12,747	41.7	%
Total other revenues	$	55,603	$	40,348	$	15,255	37.8	%
Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations	$	634,944	$	567,253	$	67,691	11.9	%
Appalachia Coal Operations		377,115		335,756		41,359	12.3	%
Oil & Gas Royalties		11,859		10,785		1,074	10.0	%
Coal Royalties		17,836		15,762		2,074	13.2	%
Other, Corporate and Elimination (2)		(13,618)		(21,177)		7,559	35.7	%
Total Segment Adjusted EBITDA Expense (3)	$	1,028,136	$	908,379	$	119,757	13.2	%
Oil & Gas Royalties
Volume - BOE (4)		2,296		1,690		606	35.9	%
Oil & gas royalties	$	101,709	$	111,378	$	(9,669)	(8.7)	%
Coal Royalties
Volume - Tons sold (5)		15,168		16,475		(1,307)	(7.9)	%
Intercompany coal royalties	$	48,843	$	46,400	$	2,443	5.3	%

(1) Recast for the JC Resources Acquisition.  For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.

(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.

(3) For definitions of Segment Adjusted EBITDA and Segment Adjusted EBITDA Expense and related reconciliations to their respective comparable GAAP financial measures, please see below under "—Reconciliation of GAAP 'net

33

income' to non-GAAP 'Segment Adjusted EBITDA' and reconciliation of GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"  

(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 that were produced from coal reserves leased from our Coal Royalties Segment.

Illinois Basin Coal Operations – Segment Adjusted EBITDA increased 29.6% to $384.0 million in the 2023 Period from $296.3 million in the 2022 Period.  The increase of $87.7 million was primarily attributable to higher coal sales, which increased 17.8% to $1.01 billion in the 2023 Period from $858.6 million in the 2022 Period, partially offset by increased operating expenses. The increase in coal sales reflects higher coal sales price per ton, which increased by 14.7% compared to the 2022 Period reflecting increased domestic prices, and increased tons sold, which rose 2.7% in the 2023 Period as a result of increased sales volumes at the Warrior and Gibson South mines. Segment Adjusted EBITDA Expense increased 11.9% to $634.9 million in the 2023 Period from $567.3 million in the 2022 Period primarily as a result of increased sales volumes and higher operating expenses per ton.  Segment Adjusted EBITDA Expense per ton increased $2.86 per ton sold to $34.69 from $31.83 per ton sold in the 2022 Period primarily as a result of inflationary pressures on numerous expense items, including labor-related expenses, maintenance costs and increased sales-related expenses due to higher price realizations.

Appalachia Coal Operations – Segment Adjusted EBITDA increased 8.5% to $301.0 million for the 2023 Period from $277.5 million in the 2022 Period.  The increase of $23.5 million was primarily attributable to higher coal sales, which increased 10.6% to $676.8 million in the 2023 Period from $612.2 million in the 2022 Period, due to increased prices, partially offset by reduced sales volumes.  Coal sales prices increased by 24.3% compared to the 2022 Period primarily due to increased domestic price realizations in the region.  Coal sales volumes decreased 11.0% compared to the 2022 Period as a result of reduced export sales from our Tunnel Ridge operation and lower production across the region due to lock outages, customer plant maintenance, reduced operating units at MC Mining, and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation.  Segment Adjusted EBITDA Expense increased 12.3% to $377.1 million in the 2023 Period from $335.8 million in the 2022 Period due to higher per ton operating expenses, partially offset by lower volumes.  Segment Adjusted EBITDA Expense per ton increased 26.2% to $50.12 compared to $39.70 per ton sold in the 2022 Period, as a result of lower volumes previously discussed, purchased coal and inflationary pressures on certain expense items, most notably labor-related expenses and materials and maintenance costs, and increased sales-related expenses due to higher price realizations.

Oil & Gas Royalties – Segment Adjusted EBITDA decreased to $90.5 million for the 2023 Period from $107.9 million in the 2022 Period.  The decrease of $17.4 million was primarily due to lower average sales price per BOE, which decreased 32.8% to $44.29 per BOE, partially offset by increased volumes in the 2023 Period, which increased by 35.9%. Higher BOE volumes during the 2023 Period resulted from increased drilling and completion activities on our properties and additional volumes from oil & gas mineral interest acquisitions.

Coal Royalties – Segment Adjusted EBITDA increased 1.2% to $31.0 million for the 2023 Period from $30.6 million in the 2022 Period.  The slight increase was a result of higher average royalty rates per ton, partially offset by reduced royalty tons sold.

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

Segment Adjusted EBITDA (a non-GAAP financial measure) is defined as net income attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization and general and administrative expenses.  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.

34

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 net income, the most comparable GAAP financial measure, to consolidated Segment Adjusted EBITDA:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Net income	$	155,351	$	168,072	$	519,334	$	370,296
Noncontrolling interest		(1,652)		(364)		(4,660)		(977)
Net income attributable to ARLP	$	153,699	$	167,708	$	514,674	$	369,319
General and administrative		20,097		21,360		61,312		62,462
Depreciation, depletion and amortization		65,393		70,669		199,582		202,499
Interest expense, net		5,067		8,819		21,761		27,750
Income tax expense		3,401		6,600		11,641		55,646
Consolidated Segment Adjusted EBITDA	$	247,657	$	275,156	$	808,970	$	717,676

Segment Adjusted EBITDA Expense (a non-GAAP financial measure) includes operating expenses, coal purchases, if applicable, and other expense (income).  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 operating expenses, the most comparable GAAP financial measure, to consolidated Segment Adjusted EBITDA Expense:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(in thousands)
Operating expenses (excluding depreciation, depletion and amortization)	$	339,099	$	330,694	$	1,012,224	$	909,567
Outside coal purchases		11,530		—		15,739		151
Other expense (income)		(223)		(193)		173		(1,339)
Segment Adjusted EBITDA Expense	$	350,406	$	330,501	$	1,028,136	$	908,379

35

Liquidity and Capital Resources

Liquidity

We have historically satisfied our working capital requirements and funded our capital expenditures, investments, contractual obligations 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, contractual obligations, commitments and distribution payments. Nevertheless, our ability to satisfy our working capital requirements and additional investments, to satisfy our contractual obligations, 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. 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 being 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, 2022.

Oil & Gas Acquisitions — As of September 30, 2023, we have purchased oil & gas mineral interests for $10.0 million and $13.9 million for the three and nine months ended September 30, 2023, respectively, with cash on hand.  Future oil & gas mineral interest acquisitions are expected to be funded with cash on hand or cash generated from operations.

On February 22, 2023, we closed on the JC Resources Acquisition for $72.3 million, which was funded with cash on hand.

Please read "Item 1. Financial Statements (Unaudited) – Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for additional information about the Acquisition Agreement and the JC Resources Acquisition.

On August 22, 2023, we purchased $25.0 million of Series D Preferred Stock from Ascend with cash on hand.

On September 8, 2023, we purchased $24.6 million of Series E Preferred Stock from Infinitum with cash on hand.

Please read "Item 1. Financial Statements (Unaudited) – Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q for additional information about the Ascend and Infinitum investments.

Credit Facility — On January 13, 2023, Alliance Coal, as borrower, entered into a Credit Agreement (the "Credit Agreement") with various financial institutions.  The Credit Agreement provides for a $425 million revolving credit facility, which includes a sublimit of $15.0 million for swingline borrowings and permits the issuance of letters of credit of up to the full amount of $425 million (the "Revolving Credit Facility"), and for a term loan in an aggregate principal amount of $75 million (the "Term Loan").  The Credit Agreement matures on March 9, 2027, at which time the aggregate outstanding principal amount of all Revolving Credit Facility advances and all Term Loan advances are required to be repaid in full.  The Credit Agreement will instead mature on January 30, 2025, if on that date our Senior Notes are still outstanding and Alliance Coal does not have liquidity of at least $200 million.  Interest is payable quarterly, with principal of the Term Loan due in quarterly installments equal to 6.25% of the original principal amount of the Term Loan beginning with the quarter ending June 30, 2023, and the balance payable at maturity.  The Revolving Credit Facility replaces the $459.5 million revolving credit facility, which included a sublimit of $125.0 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings, extended to the Intermediate Partnership under its Fifth Amended and Restated Credit Agreement, dated as of March 9, 2020 that would have expired on March 9, 2024. The Credit Agreement is guaranteed by ARLP and certain of its subsidiaries, including the Intermediate Partnership and most of the direct and indirect subsidiaries of Alliance Coal (the "Subsidiary Guarantors").  The Credit Agreement also is secured by substantially all of the assets of the Subsidiary Guarantors and Alliance Coal. For additional information on the Credit Agreement, please see "Item 1. Financial Statements (Unaudited) – Note 6 – Long-Term Debt."

36

Accounts Receivable Securitization — In January 2023, we extended the term of our $60.0 million accounts receivable securitization facility (the "Securitization Facility") from January 2023 to January 2024. For additional information on the Securitization Facility, please see "Item 1. Financial Statements (Unaudited) – Note 6 – Long-Term Debt."

Unit Repurchase Program — In May 2018, the Board of Directors approved the establishment of a unit repurchase program authorizing us to repurchase up to $100 million of ARLP common units. In January 2023, the Board of Directors authorized a $93.5 million increase to the unit repurchase program, which had $6.5 million of available capacity as of December 31, 2022. 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. During the nine months ended September 30, 2023, we repurchased and retired 929,842 units at an average price of $20.90 for an aggregate purchase price of $19.4 million. The timing of any future unit repurchases and the ultimate number of units to be purchased will depend on several 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 the unit repurchase program.

Repurchase or Redemption of Senior Notes — During the nine months ended September 30, 2023, we repurchased or redeemed $115.4 million of our 7.5% senior notes due 2025. At September 30, 2023, the aggregate principal amount of our outstanding 7.5% senior notes due 2025 was $284.6 million. We expect to continue making additional purchases or redemptions with available cash flows and/or additional borrowings.

Shelf Registration Statement — We currently have an effective universal shelf Registration Statement on Form S-3 that provides for the registration and sale of an unspecified amount of our equity or debt securities. We may over time, and subject to market conditions, in one or more offerings, offer and sell any of the securities described in the prospectus.

Cash Flows

Cash provided by operating activities was $735.4 million for the 2023 Period compared to $556.2 million for the 2022 Period.  The increase in cash provided by operating activities was primarily due to an increase in net income adjusted for non-cash items and favorable working capital changes related primarily to trade receivables, accounts payable and workers' compensation accruals. These increases were partially offset by unfavorable working capital changes related primarily to inventories, accrued taxes other than income taxes, as well as miscellaneous other changes compared to the 2022 Period.

Net cash used in investing activities was $444.5 million for the 2023 Period compared to $247.5 million for the 2022 Period. The increase in cash used in investing activities was primarily attributable to increases in capital expenditures, changes in accounts payable and accrued liabilities, purchases of equity securities and acquisitions of oil & gas reserves including the JC Resources Acquisition. These increases were partially offset by decreased equity method investments. Please read "Item 1. Financial Statements (Unaudited) - Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for additional information about the JC Resources Acquisition and other oil & gas reserve acquisitions.

Net cash used in financing activities was $389.7 million for the 2023 Period compared to $152.6 million for the 2022 Period. The increase in cash used in financing activities was primarily attributable to increased cash distributions paid to unitholders, the repurchase and redemption of senior notes during the 2023 Period, debt issuance costs, settlements under deferred compensation plans and the purchase of units under the unit repurchase program. These increases were partially offset by increased long-term borrowings.

37

Cash Requirements

Management anticipates having sufficient cash flow to meet 2023 cash requirements, including capital expenditures, scheduled payments on long-term debt, lease obligations, asset retirement obligation costs and workers' compensation and pneumoconiosis costs, with our September 30, 2023 cash and cash equivalents of $197.2 million, cash flows from operations, or borrowings under our Revolving Credit Facility and Securitization Facility, if necessary.  We currently project average estimated annual maintenance capital expenditures over the next five years of approximately $7.05 per ton produced.  Our anticipated total capital expenditures, including maintenance capital expenditures, for 2023 are estimated in a range of $390.0 million to $440.0 million.  We will continue to have significant cash 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

See "Item 1. Financial Statements (Unaudited)—Note 6 – Long-Term Debt" of this Quarterly Report on Form 10-Q for a discussion of our long-term debt obligations.

We also have an agreement with a bank to provide additional letters of credit in the 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, 2023, 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 as well as other related parties. 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) the purchase of oil & gas mineral interests from JC Resources LP, an entity owned by Mr. Craft. Please read "Item 1. Financial Statements (Unaudited) – Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for more information on the purchase of oil & gas mineral interests. We also have related-party transactions with (a) WKY CoalPlay, LLC regarding three mineral leases, and (b) with entities in which we hold equity investments. For more information regarding our investments, please read "Item 1. Financial Statements (Unaudited)—Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q.  Please read our Annual Report on Form 10-K for the year ended December 31, 2022, "Item 8. Financial Statements and Supplementary Data—Note 22 – Related-Party Transactions" for additional information concerning related-party transactions.

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.  Also, a significant decline in oil & gas 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.

38

Credit Risk

Most of our coal is sold to U.S. 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 prepayments 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 "Item 1. Financial Statements (Unaudited)—Note 6– Long-Term Debt" of this Quarterly Report on Form 10-Q for more information on our Securitization Facility.

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 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 on any amounts drawn under these facilities.  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 did not have an outstanding balance under either the Revolving Credit Facility or the Securitization Facility at September 30, 2023.  

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, 2022.

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, 2023.  Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these controls and procedures are effective as of September 30, 2023.

During the quarterly period ended September 30, 2023, 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.

39

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:

● 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;

● changes in macroeconomic and market conditions and market volatility, and the impact of such changes and volatility on our financial position;

● changes in global economic and geo-political conditions or changes in industries in which our customers operate;

● changes in commodity prices, demand and availability which could affect our operating results and cash flows;

● the outcome or escalation of current hostilities in Ukraine and the Israel-Gaza conflict;

● the severity, magnitude, and duration of any future pandemics and impacts of such pandemics and of businesses' and governments' responses to such pandemics 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;

● 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;

● 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 oil & gas mineral interests due to low commodity 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 and to successfully integrate such acquisitions into our business and achieve the anticipated benefits therefrom;

● our ability to identify and invest in new energy and infrastructure transition ventures;

● the success of our development plans for our wholly owned subsidiary, Matrix Design Group, LLC, and our investments in emerging infrastructure and technology companies;

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

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

● the effects of and changes in trade, monetary and fiscal policies and laws;

● central bank policy actions, bank failures and associated liquidity risks;

● the effects of and changes in taxes or tariffs and other trade measures adopted by the United States and foreign governments;

● 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 ("ESG") 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;

40

● 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 equipment, raw material, service or labor costs or availability, including due to inflationary pressures;

● changes in our ability to recruit, hire and maintain labor;

● our ability to maintain satisfactory relations with our employees;

● 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, supply chain shortage of equipment or mine supplies, 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 mineral reserves and resources;

● 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;

● uncertainties in the future of the electric vehicle industry and the market for EV charging stations;

● 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, 2022.

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 www.arlp.com; and

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

41

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 state law 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.  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.).  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.).  The plaintiffs in these cases seek class and collective action certification, which we oppose, and the courts have not yet made definitive final rulings on these issues.  The plaintiffs seek to recover alleged compensatory, liquidated and/or exemplary damages for the alleged underpayment, and costs and fees that potentially may be recoverable under applicable law. We believe our ultimate exposure, if any, will not be material to our results of operations or financial position; however, if our current belief as to the merit of the claims 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.

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, 2022 and in Part II - Item 1A. "Risk Factors" in our Form 10-Q for the quarterly period ended March 31, 2023, 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 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.  In January 2023, the Board of Directors authorized a $93.5 million increase to the unit purchase program, which had $6.5 million of available capacity as of December 31, 2022. 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, 2023, we did not repurchase and retire any units. Since inception of the unit repurchase program, we have repurchased and retired 6,390,446 units at an average unit price of $17.67 for an aggregate purchase price of $112.9 million.

42

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

During the three months ended September 30, 2023, no director or officer adopted or terminated (i) any contract, instructions or written plan for the purchase or sale of securities of the Partnership intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) and/or (ii) any written arrangement for the purchase or sale of securities of the Partnership that meets the definition of a non-Rule 10b5-1 trading arrangement as defined in Item 408(c).

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

43

		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*
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
10.1	Eleventh Amendment to the Receivables Financing Agreement, dated as of January 13, 2023.	10-K	000-26823 23666549	10.54	02/24/2023
10.2	Credit Agreement, dated as of January 13, 2023, among Alliance Coal, LLC, as borrower, Alliance Resource Operating Partners, L.P., Alliance Resource Partners, L.P., UC Coal, LLC, UC Mining, LLC, UC Processing, LLC and MGP II, LLC as additional Alliance entities and the initial lenders, initial issuing banks and swingline bank named therein, PNC Bank, National Association as administrative agent and collateral agent and PNC Capital Markets LLC, BOKF, NA DBA Bank of Oklahoma, Fifth Third Bank, National Association, Old National Bank and Trust Securities, Inc. as joint lead arrangers and joint bookrunners and the other institutions named therein as documentation agents.	8-K	000-26823 23540292	10.1	01/20/2023
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 8, 2023, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Cary P. Marshall, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 8, 2023, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

44

		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*
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 8, 2023, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Cary P. Marshall, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated November 8, 2023, 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, 2023 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.

45

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 8, 2023.

ALLIANCE RESOURCE PARTNERS, L.P.
By:	Alliance Resource Management GP, LLC
	its general partner
	/s/ Joseph W. Craft, III
	Joseph W. Craft, III
	Chairman, President and Chief Executive
	Officer, duly authorized to sign on behalf of the registrant.
	/s/ Megan J. Cordle
	Megan J. Cordle
	Vice President, Controller and
	Chief Accounting Officer

46