UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

_______________________________________________________________________________________________________________________________________________________________________________________________________

FORM 10-Q


(Mark One)
☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended	~~September~~June 30, ~~2022~~2023


☐						TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
						For the transition period from to

Commission file number 1-9172

NACCO INDUSTRIES, INC.

(Exact name of registrant as specified in its charter)

Delaware

34-1505819

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer Identification No.)

5875 Landerbrook Drive

Suite 220

Cleveland,

Ohio

44124-4069

(Address of principal executive offices)

(Zip code)

(440)

229-5151

(Registrant's telephone number, including area code)

N/A

(Former name, former address and former fiscal year, if changed since last report)

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

Title of each class

Trading Symbol

Name of each exchange on which registered

Class A Common Stock, $1 par value per share

New York Stock Exchange

Class B Common Stock is not publicly listed for trade on any exchange or market system; however, Class B Common Stock is convertible into Class A Common Stock on a share-for-share basis.

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes þ No o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Yes þ No o

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. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No þ

Number of shares of Class A Common Stock outstanding at ~~October~~July 28, ~~2022: 5,775,954~~2023: 5,954,638

Number of shares of Class B Common Stock outstanding at ~~October~~July 28, ~~2022: 1,566,329~~2023: 1,565,829

NACCO INDUSTRIES, INC.

TABLE OF CONTENTS

Page Number

Part I.

FINANCIAL INFORMATION

Item 1

Financial Statements

Unaudited Condensed Consolidated Balance Sheets

Unaudited Condensed Consolidated Statements of Operations

Unaudited Condensed Consolidated Statements of Comprehensive Income

Unaudited Condensed Consolidated Statements of Cash Flows

Unaudited Condensed Consolidated Statements of Changes in Equity

Notes to Unaudited Condensed Consolidated Financial Statements

Item 2

Management's Discussion and Analysis of Financial Condition and Results of Operations

Item 3

Quantitative and Qualitative Disclosures About Market Risk

3234

Item 4

Controls and Procedures

Unregistered Sales of Equity Securities and Use of Proceeds

3537

Item 3

Defaults Upon Senior Securities

3537

Item 4

Mine Safety Disclosures

Part I

FINANCIAL INFORMATION

Item 1. Financial Statements

NACCO INDUSTRIES, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS


		SEPTEMBER 30 2022		DECEMBER 31 2021			JUNE 30 2023		DECEMBER 31 2022
		(In thousands, except share data)					(In thousands, except share data)
ASSETS	ASSETS					ASSETS
Cash and cash equivalents	Cash and cash equivalents	$	92,754	$	86,005	Cash and cash equivalents	$	117,016	$	110,748
Trade accounts receivable	Trade accounts receivable	23,603		25,667		Trade accounts receivable	46,047		37,940
Accounts receivable from affiliates	Accounts receivable from affiliates	6,672		5,605		Accounts receivable from affiliates	9,590		6,638
Inventories	Inventories	61,799		54,085		Inventories	65,210		71,488

Federal income tax receivable	Federal income tax receivable	23,046		15,054		Federal income tax receivable	4,272		15,687
Prepaid insurance	Prepaid insurance	4,249		2,016		Prepaid insurance	7,150		1,999
Other current assets	Other current assets	17,156		14,621		Other current assets	12,826		15,907
Total current assets	Total current assets	229,279		203,053		Total current assets	262,111		260,407
Property, plant and equipment, net	Property, plant and equipment, net	213,435		193,167		Property, plant and equipment, net	224,302		217,952

Intangibles, net	Intangibles, net	29,001		31,774		Intangibles, net	26,401		28,055

Investments in unconsolidated subsidiaries	Investments in unconsolidated subsidiaries	9,853		19,090		Investments in unconsolidated subsidiaries	11,064		14,927
Operating lease right-of-use assets	Operating lease right-of-use assets	7,912		8,911		Operating lease right-of-use assets	6,121		6,419
Investment in private company equity units		19,958		5,000

Other non-current assets	Other non-current assets	50,766		46,225		Other non-current assets	41,511		40,312
Total assets	Total assets	$	560,204	$	507,220	Total assets	$	571,510	$	568,072
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Accounts payable	Accounts payable	$	11,371	$	12,208	Accounts payable	$	12,898	$	11,952
Accounts payable to affiliates	Accounts payable to affiliates	699		741		Accounts payable to affiliates	158		1,362

Current maturities of long-term debt	Current maturities of long-term debt	2,955		2,527		Current maturities of long-term debt	3,675		3,649
Asset retirement obligations	Asset retirement obligations	1,820		1,820		Asset retirement obligations	2,497		1,746
Accrued payroll	Accrued payroll	16,640		16,339		Accrued payroll	9,849		18,105

Deferred revenue	Deferred revenue	1,334		4,082		Deferred revenue	1,122		833

Other current liabilities	Other current liabilities	9,150		8,299		Other current liabilities	7,312		6,623
Total current liabilities	Total current liabilities	43,969		46,016		Total current liabilities	37,511		44,270
Long-term debt	Long-term debt	15,322		18,183		Long-term debt	20,054		16,019
Operating lease liabilities	Operating lease liabilities	8,944		9,733		Operating lease liabilities	7,048		7,528
Asset retirement obligations	Asset retirement obligations	43,326		42,131		Asset retirement obligations	46,890		44,256
Pension and other postretirement obligations	Pension and other postretirement obligations	4,943		6,605		Pension and other postretirement obligations	4,307		5,082
Deferred income taxes	Deferred income taxes	11,299		14,792		Deferred income taxes	4,746		6,122
Liability for uncertain tax positions	Liability for uncertain tax positions	9,280		10,113		Liability for uncertain tax positions	9,004		9,329
Other long-term liabilities	Other long-term liabilities	7,700		7,531		Other long-term liabilities	8,552		8,500
Total liabilities	Total liabilities	144,783		155,104		Total liabilities	138,112		141,106
Stockholders' equity	Stockholders' equity					Stockholders' equity
Common stock:	Common stock:					Common stock:
Class A, par value $1 per share, 5,775,910 shares outstanding (December 31, 2021 - 5,616,568 shares outstanding)		5,776		5,616
Class B, par value $1 per share, convertible into Class A on a one-for-one basis, 1,566,373 shares outstanding (December 31, 2021 - 1,566,613 shares outstanding)		1,566		1,567
Class A, par value $1 per share, 5,954,538 shares outstanding (December 31, 2022 - 5,782,944 shares outstanding)						Class A, par value $1 per share, 5,954,538 shares outstanding (December 31, 2022 - 5,782,944 shares outstanding)	5,954		5,783
Class B, par value $1 per share, convertible into Class A on a one-for-one basis, 1,565,929 shares outstanding (December 31, 2022 - 1,566,129 shares outstanding)						Class B, par value $1 per share, convertible into Class A on a one-for-one basis, 1,565,929 shares outstanding (December 31, 2022 - 1,566,129 shares outstanding)	1,566		1,566
Capital in excess of par value	Capital in excess of par value	23,235		16,331		Capital in excess of par value	24,906		23,706
Retained earnings	Retained earnings	392,666		336,778		Retained earnings	409,946		404,924
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(7,822)		(8,176)		Accumulated other comprehensive loss	(8,974)		(9,013)
Total stockholders' equity	Total stockholders' equity	415,421		352,116		Total stockholders' equity	433,398		426,966
Total liabilities and equity	Total liabilities and equity	$	560,204	$	507,220	Total liabilities and equity	$	571,510	$	568,072

See notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

NACCO INDUSTRIES, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


		THREE MONTHS ENDED				NINE MONTHS ENDED					THREE MONTHS ENDED				SIX MONTHS ENDED
		SEPTEMBER 30				SEPTEMBER 30					JUNE 30				JUNE 30
		2022		2021		2022		2021			2023		2022		2023		2022
		(In thousands, except per share data)									(In thousands, except per share data)
Revenues	Revenues	$	61,793	$	51,742	$	178,185	$	142,743	Revenues	$	61,350	$	61,369	$	111,491	$	116,392
Cost of sales	Cost of sales	43,965		37,413		128,867		111,737		Cost of sales	54,943		45,726		101,727		84,902
Gross profit	Gross profit	17,828		14,329		49,318		31,006		Gross profit	6,407		15,643		9,764		31,490
Earnings of unconsolidated operations	Earnings of unconsolidated operations	14,588		17,652		43,802		46,536		Earnings of unconsolidated operations	11,084		14,622		24,908		29,214
Contract termination settlement	Contract termination settlement	—		10,333		14,000		10,333		Contract termination settlement	—		14,000		—		14,000
Operating expenses	Operating expenses									Operating expenses
Selling, general and administrative expenses	Selling, general and administrative expenses	17,790		13,830		48,415		40,471		Selling, general and administrative expenses	14,746		15,841		29,622		30,625
Amortization of intangible assets	Amortization of intangible assets	867		902		2,772		2,795		Amortization of intangible assets	927		1,058		1,654		1,905
(Gain) loss on sale of assets		2		(10)		(2,451)		17
Asset impairment charges		3,939		—		3,939		—
Loss (gain) on sale of assets										Loss (gain) on sale of assets	68		(2,317)		(168)		(2,453)

		22,598		14,722		52,675		43,283			15,741		14,582		31,108		30,077
Operating profit	Operating profit	9,818		27,592		54,445		44,592		Operating profit	1,750		29,683		3,564		44,627
Other (income) expense	Other (income) expense									Other (income) expense
Interest expense	Interest expense	486		493		1,495		1,208		Interest expense	572		496		1,117		1,009
Interest income	Interest income	(352)		(101)		(692)		(321)		Interest income	(1,714)		(195)		(2,869)		(340)
Closed mine obligations	Closed mine obligations	398		372		1,155		1,119		Closed mine obligations	433		377		842		757
Loss (gain) on equity securities		316		(445)		1,676		(2,530)
Income from equity method investee		(2,156)		—		(2,156)		—
(Gain) loss on equity securities										(Gain) loss on equity securities	(421)		1,878		(1,049)		1,360

Other contract termination settlements	Other contract termination settlements	—		—		(16,882)		—		Other contract termination settlements	—		(16,882)		—		(16,882)
Other, net	Other, net	(354)		(161)		(1,648)		(418)		Other, net	(377)		(1,064)		(2,102)		(1,294)
		(1,662)		158		(17,052)		(942)			(1,507)		(15,390)		(4,061)		(15,390)
Income before income tax provision		11,480		27,434		71,497		45,534
Income tax provision		866		2,597		11,121		5,231
Income before income tax provision (benefit)										Income before income tax provision (benefit)	3,257		45,073		7,625		60,017
Income tax provision (benefit)										Income tax provision (benefit)	737		7,893		(587)		10,255
Net income	Net income	$	10,614	$	24,837	$	60,376	$	40,303	Net income	$	2,520	$	37,180	$	8,212	$	49,762

Earnings per share:	Earnings per share:									Earnings per share:
Basic earnings per share	Basic earnings per share	$	1.45	$	3.47	$	8.27	$	5.65	Basic earnings per share	$	0.34	$	5.07	$	1.10	$	6.83
Diluted earnings per share	Diluted earnings per share	$	1.45	$	3.47	$	8.24	$	5.63	Diluted earnings per share	$	0.34	$	5.07	$	1.09	$	6.79

Basic weighted average shares outstanding	Basic weighted average shares outstanding	7,337		7,165		7,302		7,136		Basic weighted average shares outstanding	7,513		7,330		7,465		7,286
Diluted weighted average shares outstanding	Diluted weighted average shares outstanding	7,337		7,165		7,329		7,153		Diluted weighted average shares outstanding	7,513		7,330		7,515		7,325

See notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

NACCO INDUSTRIES, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


		THREE MONTHS ENDED				NINE MONTHS ENDED					THREE MONTHS ENDED				SIX MONTHS ENDED
		SEPTEMBER 30				SEPTEMBER 30					JUNE 30				JUNE 30
		2022		2021		2022		2021			2023		2022		2023		2022
		(In thousands)									(In thousands)
Net income	Net income	$	10,614	$	24,837	$	60,376	$	40,303	Net income	$	2,520	$	37,180	$	8,212	$	49,762

Reclassification of pension and postretirement adjustments into earnings, net of $38 and $105 tax benefit in the three and nine months ended September 30, 2022, respectively, and net of $42 and $127 tax benefit in the three and nine months ended September 30, 2021, respectively.		118		143		354		429
Reclassification of pension and postretirement adjustments into earnings, net of $6 and $12 tax benefit in the three and six months ended June 30, 2023, respectively, and net of $32 and $67 tax benefit in the three and six months ended June 30, 2022, respectively.										Reclassification of pension and postretirement adjustments into earnings, net of $6 and $12 tax benefit in the three and six months ended June 30, 2023, respectively, and net of $32 and $67 tax benefit in the three and six months ended June 30, 2022, respectively.	18		118		39		236
Total other comprehensive income	Total other comprehensive income	118		143		354		429		Total other comprehensive income	18		118		39		236
Comprehensive income	Comprehensive income	$	10,732	$	24,980	$	60,730	$	40,732	Comprehensive income	$	2,538	$	37,298	$	8,251	$	49,998

See notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

NACCO INDUSTRIES, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS


		NINE MONTHS ENDED					SIX MONTHS ENDED
		SEPTEMBER 30					JUNE 30
		2022		2021			2023		2022
		(In thousands)					(In thousands)
Operating activities	Operating activities					Operating activities

Net cash provided by operating activities	Net cash provided by operating activities	$	54,929	$	67,794	Net cash provided by operating activities	$	23,287	$	40,481

Investing activities	Investing activities					Investing activities
Expenditures for property, plant and equipment and acquisition of mineral interests	Expenditures for property, plant and equipment and acquisition of mineral interests	(42,004)		(35,534)		Expenditures for property, plant and equipment and acquisition of mineral interests	(14,135)		(24,918)
Proceeds from the sale of property, plant and equipment	Proceeds from the sale of property, plant and equipment	2,824		547		Proceeds from the sale of property, plant and equipment	298		2,824
Proceeds from the sale of private company equity units						Proceeds from the sale of private company equity units	1,153		—

Other	Other	(58)		(52)		Other	(15)		(22)
Net cash used for investing activities	Net cash used for investing activities	(39,238)		(35,039)		Net cash used for investing activities	(12,699)		(22,116)

Financing activities	Financing activities					Financing activities
Additions to long-term debt	Additions to long-term debt	1,664		3,633		Additions to long-term debt	1,121		1,109
Reductions of long-term debt	Reductions of long-term debt	(2,118)		(3,131)		Reductions of long-term debt	(2,251)		(1,400)
Net reductions to revolving credit agreements	Net reductions to revolving credit agreements	(4,000)		(30,000)		Net reductions to revolving credit agreements	—		(4,000)
Cash dividends paid	Cash dividends paid	(4,488)		(4,200)		Cash dividends paid	(3,190)		(2,966)

Net cash used for financing activities	Net cash used for financing activities	(8,942)		(33,698)		Net cash used for financing activities	(4,320)		(7,257)

Cash and cash equivalents	Cash and cash equivalents					Cash and cash equivalents
Total increase (decrease) for the period		6,749		(943)
Total increase for the period						Total increase for the period	6,268		11,108
Balance at the beginning of the period	Balance at the beginning of the period	86,005		88,450		Balance at the beginning of the period	110,748		86,005
Balance at the end of the period	Balance at the end of the period	$	92,754	$	87,507	Balance at the end of the period	$	117,016	$	97,113

See notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

NACCO INDUSTRIES, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY


		Class A Common Stock		Class B Common Stock		Capital in Excess of Par Value		Retained Earnings		Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity			Class A Common Stock		Class B Common Stock		Capital in Excess of Par Value		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total Stockholders' Equity
		(In thousands, except per share data)										(In thousands, except per share data)
Balance, January 1, 2021		$	5,490	$	1,568	$	10,895	$	294,270	$	(11,599)		$	300,624
Stock-based compensation		92		—		923		—		—			1,015
Conversion of Class B to Class A shares		1		(1)		—		—		—			—
Net income		—		—		—		8,961		—			8,961
Cash dividends on Class A and Class B common stock: $0.1925 per share		—		—		—		(1,374)		—			(1,374)
Reclassification adjustment to net income, net of tax		—		—		—		—		143			143
Balance, March 31, 2021		$	5,583	$	1,567	$	11,818	$	301,857	$	(11,456)		$	309,369
Stock-based compensation		12		—		1,110		—		—			1,122
Net income		—		—		—		6,505		—			6,505
Cash dividends on Class A and Class B common stock: $0.1975 per share		—		—		—		(1,412)		—			(1,412)
Reclassification adjustment to net income, net of tax		—		—		—		—		143			143
Balance, June 30, 2021		$	5,595	$	1,567	$	12,928	$	306,950	$	(11,313)		$	315,727
Stock-based compensation		12		—		1,614		—		—			1,626
Net income		—		—		—		24,837		—			24,837
Cash dividends on Class A and Class B common stock: $0.1975 per share		—		—		—		(1,414)		—			(1,414)
Reclassification adjustment to net income, net of tax		—		—		—		—		143			143
Balance, September 30, 2021		$	5,607	$	1,567	$	14,542	$	330,373	$	(11,170)		$	340,919

Balance, January 1, 2022	Balance, January 1, 2022	$	5,616	$	1,567	$	16,331	$	336,778	$	(8,176)		$	352,116	Balance, January 1, 2022	$	5,616	$	1,567	$	16,331	$	336,778	$	(8,176)	$	352,116
Stock-based compensation	Stock-based compensation	145		—		978		—		—			1,123		Stock-based compensation	145		—		978		—		—		1,123

Conversion of Class B to Class A shares	Conversion of Class B to Class A shares	1		(1)		—		—		—			—		Conversion of Class B to Class A shares	1		(1)		—		—		—		—
Net income	Net income	—		—		—		12,582		—			12,582		Net income	—		—		—		12,582		—		12,582
Cash dividends on Class A and Class B common stock: $0.1975 per share	Cash dividends on Class A and Class B common stock: $0.1975 per share	—		—		—		(1,445)		—			(1,445)		Cash dividends on Class A and Class B common stock: $0.1975 per share	—		—		—		(1,445)		—		(1,445)
Reclassification adjustment to net income, net of tax	Reclassification adjustment to net income, net of tax	—		—		—		—		118			118		Reclassification adjustment to net income, net of tax	—		—		—		—		118		118
Balance, March 31, 2022	Balance, March 31, 2022	$	5,762	$	1,566	$	17,309	$	347,915	$	(8,058)		$	364,494	Balance, March 31, 2022	$	5,762	$	1,566	$	17,309	$	347,915	$	(8,058)	$	364,494
Stock-based compensation	Stock-based compensation	7		—		2,325		—		—			2,332		Stock-based compensation	7		—		2,325		—		—		2,332

Net income	Net income	—		—		—		37,180		—			37,180		Net income	—		—		—		37,180		—		37,180
Cash dividends on Class A and Class B common stock: $0.2075 per share	Cash dividends on Class A and Class B common stock: $0.2075 per share	—		—		—		(1,521)		—			(1,521)		Cash dividends on Class A and Class B common stock: $0.2075 per share	—		—		—		(1,521)		—		(1,521)
Reclassification adjustment to net income, net of tax	Reclassification adjustment to net income, net of tax	—		—		—		—		118			118		Reclassification adjustment to net income, net of tax	—		—		—		—		118		118
Balance, June 30, 2022	Balance, June 30, 2022	$	5,769	$	1,566	$	19,634	$	383,574	$	(7,940)		$	402,603	Balance, June 30, 2022	$	5,769	$	1,566	$	19,634	$	383,574	$	(7,940)	$	402,603

Balance, January 1, 2023															Balance, January 1, 2023	$	5,783	$	1,566	$	23,706	$	404,924	$	(9,013)	$	426,966
Stock-based compensation	Stock-based compensation	7		—		3,601		—		—			3,608		Stock-based compensation	161		—		403		—		—		564

Net income	Net income	—		—		—		10,614		—			10,614		Net income	—		—		—		5,692		—		5,692
Cash dividends on Class A and Class B common stock: $0.2075 per share	Cash dividends on Class A and Class B common stock: $0.2075 per share	—		—		—		(1,522)		—			(1,522)		Cash dividends on Class A and Class B common stock: $0.2075 per share	—		—		—		(1,557)		—		(1,557)
Reclassification adjustment to net income, net of tax	Reclassification adjustment to net income, net of tax	—		—		—		—		118			118		Reclassification adjustment to net income, net of tax	—		—		—		—		21		21
Balance, September 30, 2022		$	5,776	$	1,566	$	23,235	$	392,666	$	(7,822)		$	415,421
Balance, March 31, 2023															Balance, March 31, 2023	$	5,944	$	1,566	$	24,109	$	409,059	$	(8,992)	$	431,686
Stock-based compensation															Stock-based compensation	10		—		797		—		—		807

Net income															Net income	—		—		—		2,520		—		2,520
Cash dividends on Class A and Class B common stock: $0.2175 per share															Cash dividends on Class A and Class B common stock: $0.2175 per share	—		—		—		(1,633)		—		(1,633)
Reclassification adjustment to net income, net of tax															Reclassification adjustment to net income, net of tax	—		—		—		—		18		18
Balance, June 30, 2023															Balance, June 30, 2023	$	5,954	$	1,566	$	24,906	$	409,946	$	(8,974)	$	433,398

See notes to Unaudited Condensed Consolidated Financial Statements.

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NACCO INDUSTRIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~SEPTEMBER~~JUNE 30, ~~2022~~2023

(In thousands, except as noted and per share amounts)

NOTE 1—Nature of Operations and Basis of Presentation

The accompanying Unaudited Condensed Consolidated Financial Statements include the accounts of NACCO Industries, Inc.® (“NACCO”) and its wholly owned subsidiaries (collectively, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines for power generation companies. The NAMining segment is a trusted mining partner for producers of aggregates, activated carbon, lithium and other industrial minerals. The Minerals Management segment, which includes the Catapult Mineral Partners ("Catapult") business, acquires and promotes the development of mineral interests. Mitigation Resources of North America® ("Mitigation Resources") provides stream and wetland mitigation solutions.

The Company also has items not directly attributable to a reportable segment. Intercompany accounts and transactions are eliminated in consolidation.

Effective January 1, 2022, the Company changed the composition of its reportable segments. As a result, the Company retrospectively changed its computation of segment operating profit to reclassify the results of Caddo Creek Resources Company, LLC (“Caddo Creek”) and Demery Resources Company, LLC ("Demery") from the Coal Mining segment into the NAMining segment as these operations provide mining solutions for producers of industrial minerals, rather than for power generation. The Coal Mining segment now includes only mines that deliver coal to power generation companies. This segment reporting change has no impact on consolidated operating results. All prior period segment information has been reclassified to conform to the new presentation. See Note 8 to the Unaudited Condensed Consolidated Financial Statements for further discussion of segment reporting.

The Company’s operating segments are further described below:

Coal Mining Segment

The Coal Mining segment, operating as ~~The~~ North American Coal, ~~Corporation~~®LLC ("NACoal"), operates surface coal mines under long-term contracts with power generation companies pursuant to a service-based business model. ~~Lignite coal~~Coal is surface mined in North Dakota ~~Texas~~ and Mississippi. Each mine is fully integrated with its customer's ~~operations and is the exclusive supplier of coal to its customer's facilities.~~operations.

During the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, the Coal Mining segment's operating coal mines were: The Coteau Properties Company (“Coteau”), Coyote Creek Mining Company, LLC (“Coyote Creek”), The Falkirk Mining Company (“Falkirk”), and Mississippi Lignite Mining Company (“MLMC”) ~~and~~ .

The Sabine Mining Company (“Sabine”). Each of these mines deliver their coal production to adjacent power plants or synfuels plants under long-term supply contracts. MLMC’s coal supply contract contains a take or pay provision; all other coal supply contracts are requirements contracts under which earnings can fluctuate. Certain coal supply contracts can be terminated early, which would result in a reduction to future earnings.

On May 2, 2022, Great River Energy (“GRE”) completed the sale of Coal Creek Station and the adjacent high-voltage direct current transmission line to Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. As a result of the completion of the sale of Coal Creek Station, the Coal Sales Agreement, the Mortgage and Security Agreement and the Option Agreement between GRE and Falkirk were terminated. The Company recognized a gain of $30.9 million within the accompanying Unaudited Condensed Consolidated Statements of Operations during the second quarter of 2022 as GRE paid NACoal $14.0 million in cash, as well as transferred ownership of an office building with an estimated fair value of $4.1 million, and conveyed membership units in a privately-held company involved in the ethanol industrywith an estimated fair value of $12.8 million, as agreed to under the termination and release of claims agreement between Falkirk and GRE. See Note 5 for further discussion on fair value. Prior to receiving the membership units from GRE, the Company held a $5.0 million investment in the same privately-held company carried at cost, less impairment. Subsequent to the receipt of the additional membership units on May 2, 2022, the Company began to account for the investment under the equity method of accounting subject to a one quarter reporting lag.

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The new Coal Sales Agreement (“CSA”) between Falkirk and Rainbow Energy became effective upon the closing of the transaction. Falkirk continues to supply all coal requirements of Coal Creek Station and is paid a management fee per ton of coal delivered. To support the transfer to new ownership, Falkirk has agreed to a reduction in the current per ton management fee from the effective date of the new CSA through May 31, 2024. After May 31, 2024, the per ton management fee increases to a higher base in line with 2021 fee levels, and thereafter adjusts annually according to an index which tracks broad measures of U.S. inflation. Rainbow Energy is responsible for funding all mine operating costs, including mine reclamation, and directly or indirectly providing all of the capital required to operate the mine. The initial production period is expected to run ten years from the effective date of the CSA, but the CSA may be extended or terminated early under certain circumstances.

During the three and nine months ended September 30, 2021, the Coal Mining segment's operating coal mines also included Bisti Fuels Company, LLC (“Bisti”). Effective September 30, 2021, the contract mining agreement between Bisti and its customer, Navajo Transitional Energy Company ("NTEC"), was terminated.

Coteau operates the Freedom Mine in North Dakota. All coal production from the Freedom Mine is delivered to Basin Electric Power Cooperative (“Basin Electric”). Basin Electric utilizes the coal at the Great Plains Synfuels Plant (the “Synfuels Plant”), Antelope Valley Station and Leland Olds Station. The Synfuels Plant is a coal gasification plant, owned by Dakota Gasification Company (“Dakota Gas’), a subsidiary of Basin Electric, that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. During 2020, Basin Electric informed Coteau that it is considering changes that may result in modifications to its Synfuels Plant that could potentially reduce or eliminate coal requirements at the Synfuels Plant. During 2021, Bakken Energy (“Bakken”) and Basin Electric signed a non-binding term sheet to transfer ownership of the assets of Dakota Gas to Bakken. Bakken stated the closing date is expected to be April 1, 2023. The closing is subject to the satisfaction of specified conditions. As part of the term sheet between Basin Electric and Bakken, Basin Electric indicated that the Synfuels Plant will continue existing operations through 2026. Basin Electric is also considering other options for the Synfuels Plant if the transaction with Bakken does not close.

~~Sabine~~ operates the Sabine Mine in Texas. All production from Sabine iswas delivered to Southwestern Electric Power Company's (“SWEPCO”) Henry W. Pirkey Plant (the “Pirkey Plant”). SWEPCO is an American Electric Power (“AEP”) company. ~~AEP intends to retire~~As a result of the early retirement of the Pirkey Plant, ~~in 2023.~~ Sabine ~~expects~~ceased deliveries ~~to cease during~~in the first quarter of 2023 ~~at which time it expects to begin~~and final ~~reclamation.~~reclamation began on April 1, 2023. Funding for mine reclamation is the responsibility of ~~SWEPCO.~~SWEPCO, and Sabine receives compensation for providing mine reclamation services.

The United States Environmental Protection Agency (the “EPA”) has a comprehensive regulatory program to manage the disposal of coal combustion residuals (“CCR”) from coal-fired power plants as non-hazardous material under the Resource Conservation and Recovery Act (“RCRA”). Individual states administer some or all of the RCRA provisions. The North Dakota Department of Environmental Quality approved Falkirk’s customer's plan for an alternate disposal liner to store coal ash at the Coal Creek Station power plant. In the first quarter of 2023, the EPA proposed to deny the application. If denied, a new liner or new waste management unit(s) may need to be installed which could result in the temporary suspension of operations at Coal Creek Station. To minimize any impact to operations, Coal Creek Station is moving forward with plans to dry CCR materials produced by the plant, reducing the need to utilize the lined area in question. Falkirk is the sole supplier of lignite coal to Coal Creek Station. Any suspension of operations at Coal Creek Station would eliminate the need for lignite coal during the suspension period. Any such suspension of operations at Coal Creek Station or any of the power plants supplied by the Company's mines could have a material adverse effect on the Company’s business, financial condition and results of operations. See the Government Regulation Update on page 19 of this Quarterly Report on Form 10-Q for further information.

MLMC is the exclusive supplier of lignite to the Red Hills Power Plant in Ackerman, Mississippi. Choctaw Generation Limited Partnership ("CGLP") leases the Red Hills Power Plant from a Southern Company subsidiary pursuant to a leveraged lease arrangement. CGLP's ability to make required payments to the Southern Company subsidiary is dependent on the operational performance of the Red Hills Power Plant. During 2022, Southern Company disclosed that it provided notice to the lessee, CGLP, to terminate the related operating and maintenance agreement effective June 30, 2023. Subsequently, CGLP failed to make the semi-annual lease payment due in December 2022, and as a result, the Southern Company subsidiary was unable to make its corresponding payment to the debtholders. The parties to the lease have entered into a forbearance agreement which suspends the related contractual rights of the parties while they continue restructuring negotiations, which could result in rescission of the termination notice. The ultimate outcome of this matter cannot be determined at this time but could have a material impact on the Company's financial statements if the operating and maintenance agreement is terminated.

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At Coteau, Coyote Creek ~~Falkirk~~ and ~~Sabine,~~Falkirk, the Company is paid a management fee per ton of coal or heating unit (MMBtu) delivered. Each contract specifies the indices and mechanics by which fees change over time, generally in line with broad measures of U.S. inflation. The customers are responsible for funding all mine operating costs, including final mine reclamation, and directly or indirectly provide all of the capital required to build and operate the mine. This contract structure eliminates exposure to spot coal market price fluctuations while providing income and cash flow with minimal capital investment. Other than at Coyote Creek, debt financing provided by or supported by the customers is without recourse to ~~NACCO and NACoal.~~the Company. See Note 6 for further discussion of Coyote Creek's guarantees.

Coteau, Coyote Creek, Falkirk and Sabine ~~each~~ meet the definition of a variable interest entity ("VIE"). In each case, NACCO is not the primary beneficiary of the VIE as it does not exercise financial control; therefore, NACCO does not consolidate the results of these operations within its financial statements. Instead, these contracts are accounted for as equity method investments. The income before income taxes associated with these VIEs is reported as Earnings of unconsolidated operations on the Unaudited Condensed Consolidated Statements of Operations and the Company’s investment is reported on the line Investments in unconsolidated subsidiaries in the Unaudited Condensed Consolidated Balance Sheets. The mines that meet the definition of a VIE are referred to collectively as the “Unconsolidated Subsidiaries.” For tax purposes, the Unconsolidated Subsidiaries are included within the NACCO consolidated U.S. tax return; therefore, the Income tax (benefit) provision line on the Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. See Note 6 for further information on the Unconsolidated Subsidiaries.

While Falkirk meets the definition of a VIE, the completion of the Rainbow Energy transaction resulted in a VIE reconsideration event. As the terms of the contract between Falkirk and Rainbow Energy are substantially the same as the terms of the contract between Falkirk and GRE, Falkirk will remain a VIE and Rainbow Energy is the primary beneficiary; therefore, NACCO will continue to account for Falkirk under the equity method.

The Company performs contemporaneous reclamation activities at each mine in the normal course of operations. Under all of the Unconsolidated Subsidiaries’ contracts, the customer has the obligation to fund final mine reclamation activities. Under certain contracts, the Unconsolidated Subsidiary holds the mine permit and is therefore responsible for final mine reclamation

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activities. To the extent the Unconsolidated Subsidiary performs such final reclamation, it is compensated for providing those services in addition to receiving reimbursement from customers for costs incurred.

The MLMC contract is the only operating coal contract in which the Company is responsible for all operating costs, capital requirements and final mine reclamation; therefore, MLMC is consolidated within NACCO’s financial statements. MLMC sells coal to its customer at a contractually agreed-upon price which adjusts monthly, primarily based on changes in the level of established indices which reflect general U.S. inflation rates. Profitability at MLMC is affected by customer demand for coal and changes in the indices that determine sales price and actual costs incurred. As diesel fuel is heavily weighted among the indices used to determine the coal sales price, fluctuations in diesel fuel prices can result in significant fluctuations in earnings at MLMC.

MLMC delivers coal to the Red Hills Power Plant in Ackerman, Mississippi. The Red Hills Power Plant supplies electricity to the Tennessee Valley Authority ("TVA") under a long-term Power Purchase Agreement. MLMC’s contract with its customer runs through 2032. TVA’s power portfolio includes coal, nuclear, hydroelectric, natural gas and renewables. The decision of which power plants to dispatch is determined by TVA. Reduction in dispatch of the Red Hills Power Plant will result in reduced earnings at MLMC.

NAMining Segment

The NAMining segment provides value-added contract mining and other services for producers of industrial minerals. The segment is a ~~primary~~ platform for the Company’s growth and diversification of mining activities outside of the thermal coal industry. NAMining provides contract mining services for independently owned mines and quarries, creating value for its customers by performing the mining aspects of its customers’ operations. This allows customers to focus on their areas of expertise: materials handling and processing, product sales and distribution. As of June 30, 2023, NAMining ~~historically operated primarily at limestone quarries~~operates in Florida, ~~but is focused on continuing to expand outside of Florida,~~Texas, Arkansas, Indiana, Virginia and Nebraska. Sawtooth Mining, LLC ("Sawtooth") provides comprehensive mining ~~materials other than limestone and expanding~~services as the ~~scope of mining operations provided to its customers.~~exclusive contract miner for the Thacker Pass lithium project in northern Nevada.

~~NAMining utilizes both fixed price and management fee contract structures.~~ Certain of the entities within the NAMining segment are VIEs and are accounted for under the equity method as Unconsolidated Subsidiaries. See Note 6 for further discussion.

Minerals Management Segment

The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore, develop, mine, produce, market and sell gas, oil and coal in exchange for royalty payments based on the lessees' sales of those minerals.

During the first nine months ended September 30, 2022, the Minerals Management segment had capital expenditures totaling $12.3 million, primarily related to the $11.4 million acquisition of mineral interests in the Texas portion of the Permian Basin and the Wyoming portion of the Powder River Basin during the third quarter of 2022. During the first nine months of 2022, the Minerals Management segment also acquired mineral interests in the New Mexico portion of the Permian Basin. The Minerals Management segment ~~intends~~owns royalty interests, mineral interests, non-participating royalty interests and overriding royalty interests.

•Royalty Interest. Royalty interests generally result when the owner of a mineral interest leases the underlying minerals to an exploration and production company pursuant to an oil and gas lease. Typically, the resulting royalty interest is a cost-free percentage of production revenues for minerals extracted from the acreage. A holder of royalty interests is generally not responsible for capital expenditures or lease operating expenses, but royalty interests may be calculated

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net of post-production expenses, and typically has no environmental liability. Royalty interests leased to producers expire upon the expiration of the oil and gas lease and revert to the mineral owner.

•Mineral Interest. Mineral interests are perpetual rights of the owner to explore, develop, exploit, mine and/or produce any or all of the minerals lying below the surface of the property. The holder of a mineral interest has the right to lease the minerals to an exploration and production company. Upon the execution of an oil and gas lease, the lessee (the exploration and production company) becomes the working interest owner and the lessor (the mineral interest owner) has a royalty interest.

•Non-Participating Royalty Interest (“NPRIs”). NPRI is an interest in oil and gas production which is created from the mineral estate. The NPRI is expense-free, bearing no operational costs of production. The term “non-participating” indicates that the interest owner does not share in the bonus, rentals from a lease, nor the right to participate in the execution of oil and gas leases. The NPRI owner does, however, typically receive royalty payments.

•Overriding Royalty Interest (“ORRIs”). ORRIs are created by carving out the right to receive royalties from a working interest. Like royalty interests, ORRIs do not confer an obligation to make ~~future acquisitions~~capital expenditures or pay for lease operating expenses and have limited environmental liability; however, ORRIs may be calculated net of ~~mineral~~post-production expenses, depending on how the ORRI is structured. ORRIs that are carved out of working interests are linked to the same underlying oil and ~~royalty interests~~gas lease that ~~meet~~created the ~~Company’s acquisition criteria as part~~working interest, and therefore, such ORRIs are typically subject to expiration upon the expiration or termination of ~~its growth strategy.~~the oil and gas lease.

The ~~Company’s~~Company may own more than one type of mineral and royalty interest in the same tract of land. For example, where the Company owns an ORRI in a lease on the same tract of land in which it owns a mineral interest, the ORRI in that tract will relate to the same gross acres as the mineral interest in that tract.

The Minerals Management segment will benefit from the continued development of its mineral properties without the need for investment of additional capital once mineral and royalty interests have been acquired. The Minerals Management segment does not currently have any material investments under which it would be required to bear the cost of exploration, production or development.

The Company also manages legacy royalty and mineral interests ~~are~~ located in Ohio (Utica and Marcellus shale natural gas), Louisiana (Haynesville shale and Cotton Valley formation natural gas), Texas (Cotton Valley and Austin Chalk formation natural gas), Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal, coalbed methane and natural gas) and North Dakota (coal, oil and natural gas). The majority of the Company’s legacy reserves were acquired as part of its historical coal mining operations.

Other Items: On May 2, 2022, Great River Energy (“GRE”) completed the sale of Coal Creek Station and the adjacent high-voltage direct current transmission line to Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. The ~~Minerals Management segment owns royalty interests, mineral interests, nonparticipating royalty interests,~~Coal Sales Agreement (“CSA”) between Falkirk and ~~overriding royalty interests. The Company may own more than one type~~Rainbow Energy became effective upon the closing of ~~mineral~~the transaction. Falkirk continues to supply all coal requirements of Coal Creek Station and ~~royalty interest~~is paid a management fee per ton of coal delivered. To support the transfer to new ownership, Falkirk agreed to a reduction in the ~~same tract~~current per ton management fee from the effective date of ~~land. For example, where~~ the ~~Company owns~~CSA through May 31, 2024. After May 31, 2024, the per ton management fee increases to a higher base in line with 2021 fee levels, and thereafter adjusts annually according to an ~~overriding royalty interest in a lease on~~index which tracks broad measures of U.S. inflation. Rainbow Energy is responsible for funding all mine operating costs, including mine reclamation, and directly or indirectly providing all of the ~~same tract of land in which it owns a mineral interest,~~capital required to operate the ~~overriding royalty interest in that tract will relate~~mine. The initial production period is expected to run through May 1, 2032, but the ~~same gross acres as the mineral interest in that tract.~~CSA may be extended or terminated early under certain circumstances.

The ~~Minerals Management segment will benefit from~~Company recognized a gain of $30.9 million within the ~~continued development~~accompanying Unaudited Condensed Consolidated Statements of ~~its mineral properties without~~Operations during the ~~need for investment~~second quarter of ~~additional capital once mineral~~2022 as GRE paid $14.0 million in cash, as well as transferred ownership of an office building with an estimated fair value of $4.1 million, and ~~royalty interests have been acquired. The Minerals Management segment does not have any investments under which it would be required to bear~~conveyed membership units in Midwest AgEnergy Group, LLC (“MAG”), a North Dakota-based ethanol business, with an estimated fair value at the ~~cost~~transfer date of ~~exploration, production or development.~~$12.8 million.

Prior to receiving the membership units from GRE, the Company held a $5.0 million investment in MAG carried at cost, less impairment. Subsequent to the receipt of the additional membership units, the Company began to account for the investment under the equity method of accounting. On December 1, 2022, the Company transferred its ownership interest in Midwest AgEnergy, LLC to HLCP Ethanol Holdco, LLC (“HLCP”) and received a cash payment of $18.6 million during the fourth quarter of 2022. The Company received a payment of $1.2 million in the first quarter of 2023 in connection with a post-closing purchase price adjustment, which is included on the line "Other, net" within the accompanying Unaudited Consolidated Statements of Operations.

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~~As an owner~~

The HLCP acquisition agreement includes two contingent earn-out arrangements under which additional payments are possible. The first earn-out is based on the achievement of ~~royalty and mineral interests,~~EBITDA targets through December 31, 2024. The second earn-out is based on the development of a carbon dioxide pipeline that will support a carbon dioxide sequestration project over a four-year period commencing on the transaction closing date. Additional payments to NACCO could range from $0 to approximately $12.9 million based on achievement of the two earn-outs as well as payment of amounts held in escrow to address potential indemnity claims during the 12-month period following the transaction date. Any future payments associated with the earn-outs or amounts held in escrow will be recognized when realized, consistent with the accounting for gain contingencies.

During the first quarter of 2023, the Company’s ~~access~~wholly-owned subsidiary, Caddo Creek Resources Company (“Caddo Creek”), acquired 100% of the membership interests in the Marshall Mine located outside of Marshall, Texas from Advanced Emissions Solutions (“ADES”). Prior to ~~information concerning activity and operations of its royalty and mineral interests is limited.~~the acquisition, Caddo Creek was performing mine reclamation under a fixed price contract with ADES. The Company ~~does not have information that would~~received $2.2 million of cash, assumed the asset retirement obligation estimated to be ~~available to~~approximately $1.9 million and recognized a ~~company with oil and natural gas operations because detailed information is not generally available to owners~~gain of ~~royalty and mineral interests.~~approximately $0.3 million in the first quarter of 2023.

Basis of Presentation: These financial statements have been prepared in accordance with U.S. generally accepted accounting principles ("U.S. GAAP") for interim financial information and the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation of the financial position of the Company at ~~September~~June 30, ~~2022,~~2023, the results of its operations, comprehensive income, cash flows and changes in equity for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022 have been included. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2021.~~2022.

The balance sheet at December 31, ~~2021~~2022 has been derived from the audited financial statements at that date but does not include all of the information or notes required by U.S. GAAP for complete financial statements.

~~Certain amounts in the prior period Unaudited Condensed Consolidated Financial Statements have been reclassified to conform to the current period's presentation.~~

NOTE 2—Revenue Recognition

Nature of Performance Obligations

At contract inception, the Company assesses the goods and services promised in its contracts with customers and identifies a performance obligation for each promised good or service that is distinct. To identify the performance obligations, the Company considers all of the goods or services promised in the contract regardless of whether they are explicitly stated or are implied by customary business practices.

Each mine has a contract with its respective customer that represents a contract under ASC 606. For its consolidated entities, the Company’s performance obligations vary by contract and consist of the following:

At MLMC, each MMBtu delivered during the production period is considered a separate performance obligation. Revenue is recognized at the point in time that control of each MMBtu of lignite transfers to the customer. Fluctuations in revenue from period to period generally result from changes in customer demand.

At NAMining, the management service is primarily to oversee the operation of the equipment, and delivery of aggregates or other minerals is the performance obligation accounted for as a series. Performance momentarily creates an asset that the customer simultaneously receives and consumes; therefore, control is transferred to the customer over time. Consistent with the conclusion that the customer simultaneously receives and consumes the benefits provided, an input-based measure of progress is appropriate. As each month of service is completed, revenue is recognized for the amount of actual costs incurred, plus the management fee or fixed fee and the general and administrative fee (as applicable). Fluctuations in revenue from period to period result from changes in customer demand primarily due to increases and decreases in activity levels on individual contracts and variances in reimbursable costs.

Included within NAMining, Caddo Creek has a fixed-price contract to perform mine reclamation. The management service to perform mine reclamation is the performance obligation accounted for as a series. Performance momentarily creates an asset that the customer simultaneously receives and consumes; therefore, control is transferred to the customer over time. Revenue from ~~this contract~~part sales is recognized over time utilizing the cost-to-cost method to measure the extent of progress toward completion of the performance obligation. The Company believes the cost-to-cost method is the most appropriate method to measure progress and that the rate at which costs are incurred to fulfill the contract best depicts theupon transfer of control of the parts to the customer. The extent of progress towards completion is measured based on the ratio of costs incurred to date compared to total estimated costs at completion, and revenue is recorded proportionally based on an estimated profit margin.

The Minerals Management segment enters into contracts which grant third-party lessees the right to explore, develop, produce and sell minerals controlled by the Company. These arrangements result in the transfer of mineral rights for a period of time; however, no rights to the actual land are granted other than access for purposes of exploration, development, production and sales. The mineral rights revert back to the Company at the expiration of the contract.

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Under these contracts, granting exclusive right, title, and interest in and to minerals is the performance obligation. The performance obligation under these contracts represents a series of distinct goods or services whereby each day of access that is provided is distinct. The transaction price consists of a variable sales-based royalty and, in certain arrangements, a fixed component in the form of an up-front lease bonus payment. As the amount of consideration the Company will ultimately be entitled to is entirely susceptible to factors outside its control, the entire amount of variable consideration is constrained at contract inception. The Company believes that the provisions of royalty contracts are customary in the industry. Up-front lease bonus payments represent the fixed portion of the transaction price and are recognized over the primary term of the contract, which is generally three to five years.

Mitigation Resources generates and sells stream and wetland mitigation credits (known as mitigation banking) and provides services to those engaged in permittee-responsible stream and wetland mitigation. Each mitigation credit sale is considered a separate performance obligation. Revenue is recognized at the point in time that control of each mitigation credit transfers to the customer. Fluctuations in revenue from period to period generally result from changes in customer demand. Under the permittee-responsible stream and wetland mitigation model, the contracts are generally structured as agreements under which Mitigation Resources is reimbursed for all costs incurred in performing the required mitigation plus an agreed profit percentage or a fixed fee. The mitigation services provided is the performance obligation and is accounted for as a series. Performance momentarily creates an asset that the customer simultaneously receives and consumes; therefore, control is transferred to the customer as work is completed. Consistent with the conclusion that the customer simultaneously receives and consumes the benefits provided, an input-based measure of progress is appropriate. As each month of service is completed, revenue is recognized for the amount of actual costs incurred, plus the management fee or fixed fee. Fluctuations in revenue from period to period result from changes in customer demand primarily due to increases and decreases in activity levels of individual contracts and variances in reimbursable costs.

Significant Judgments

The Company’s contracts with its customers contain different types of variable consideration including, but not limited to, management fees that adjust based on volumes or MMBtu delivered, however, the terms of these variable payments relate specifically to the Company's efforts to satisfy one or more, but not all of, the performance obligations (or to a specific outcome from satisfying the performance obligations) in the contract. Therefore, the Company allocates each variable payment (and subsequent changes to that payment) entirely to the specific performance obligation to which it relates. Management fees, as well as general and administrative fees, are also adjusted based on changes in specified indices (e.g., CPI) to compensate for general inflation changes. Index adjustments, if applicable, are effective prospectively.

Recognition of revenue and recognition of profit related to the Caddo Creek contract requires the use of assumptions and estimates related to the total contract value, the total cost at completion, and the measurement of progress towards completion of the performance obligation. Due to the nature of the contract, developing the estimated total contract value and total cost at completion requires the use of significant judgment. The total contract value includes variable consideration. The Company includes variable consideration in the transaction price at the most likely amount to be earned, based upon the Company’s assessment of expected performance. The Company records these amounts only to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.

Cost Reimbursement

Certain contracts include reimbursement from customers of actual costs incurred for the purchase of supplies, equipment and services in accordance with contractual terms. Such reimbursable revenue is variable and subject to uncertainty, as the amounts received and timing thereof is highly dependent on factors outside of the Company’s control. Accordingly, reimbursable revenue is fully constrained and not recognized until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of a customer. The Company is considered a principal in such transactions and records the associated revenue at the gross amount billed to the customer with the related costs recorded as an expense within cost of sales.

At the Thacker Pass lithium project, in addition to management fee income, the customer will reimburse Sawtooth for up to $50 million of capital expenditures. The amount is variable until the equipment is acquired. At the time the equipment is acquired, the variability is resolved as the compensation is fixed. Sawtooth will recognize revenue over the estimated useful life of the asset on a straight-line basis as the performance obligation is satisfied over time. Sawtooth began acquiring equipment for this project during the first half of 2023. Revenue recognized by Sawtooth in connection with its capital assets was immaterial in the three and six months ended June 30, 2023.

Prior Period Performance Obligations

The Company records royalty income in the month production is delivered to the purchaser. As a non-operator, the Company has limited visibility into when new wells start producing and production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, the Company is required to estimate the amount of production delivered to the purchaser of the product and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded in "Trade accounts receivable" in the accompanying Unaudited Condensed Consolidated Balance Sheets. The difference between the Company’s estimates and the actual amounts received is recorded in the month that payment is received from the third-party lessee. For the three and six months ended ~~September~~June 30, 2023, royalty income recognized in the reporting period related to performance obligations satisfied in prior reporting periods was $1.4 million. For the three months ended June 30, 2022, royalty income recognized in the reporting ~~periods~~period related to

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performance obligations satisfied in prior reporting periods was immaterial. For the ~~nine~~six months ended ~~September~~June 30, 2022, royalty income of $2.1 million was recognized for a settlement related to the Company’s ownership interest in certain mineral rights. ~~For the three and nine months ended September 30, 2021, the Company recognized $1.8 million of variable consideration that was previously constrained due to uncertainty of collectability.~~

Disaggregation of Revenue

In accordance with ASC 606-10-50, the Company disaggregates revenue from contracts with customers into major goods and service lines and timing of transfer of goods and services. The Company determined that disaggregating revenue into these categories achieves the disclosure objective of depicting how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. The Company’s business consists of the Coal Mining, NAMining and Minerals Management segments as well as Unallocated Items. See Note 8 to the Unaudited Condensed Consolidated Financial Statements for further discussion of segment reporting.

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		THREE MONTHS ENDED				NINE MONTHS ENDED					THREE MONTHS ENDED				SIX MONTHS ENDED
		SEPTEMBER 30				SEPTEMBER 30					JUNE 30				JUNE 30
		2022		2021		2022		2021			2023		2022		2023		2022
Timing of Revenue Recognition	Timing of Revenue Recognition									Timing of Revenue Recognition
Goods transferred at a point in time	Goods transferred at a point in time	$	22,043	$	20,436	$	68,402	$	61,931	Goods transferred at a point in time	$	25,729	$	25,986	$	45,875	$	46,359
Services transferred over time	Services transferred over time	39,750		31,306		109,783		80,812		Services transferred over time	35,621		35,383		65,616		70,033
Total revenues	Total revenues	$	61,793	$	51,742	$	178,185	$	142,743	Total revenues	$	61,350	$	61,369	$	111,491	$	116,392

Contract Balances

The opening and closing balances of the Company’s current and long-term accounts receivable, contract assets and contract liabilities are as follows:

Contract balances
Trade accounts receivable Contract asset
(long-term) Contract liability (current) Contract liability (long-term)
Balance, January 1, 2022 $ 25,667 $ 5,985 $ 4,082 $ 1,453
Balance, September 30, 2022 23,603 5,985 1,334 1,860
Increase (decrease) $ (2,064) $ — $ (2,748) $ 407


	Contract balances
	Trade accounts receivable		Contract asset (current)		Contract asset (long-term)		Contract liability (current)		Contract liability (long-term)
Balance, January 1, 2023	$	37,940	$	409	$	5,985	$	833	$	1,709
Balance, June 30, 2023	46,047		—		3,559		1,122		1,626
Increase (decrease)	$	8,107	$	(409)	$	(2,426)	$	289	$	(83)

As described above, the Company enters into royalty contracts that grant exclusive right, title, and interest in and to minerals. The transaction price consists of a variable sales-based royalty and, in certain arrangements, a fixed component in the form of an up-front lease bonus payment. The timing of the payment of the fixed portion of the transaction price is upfront, however, the performance obligation is satisfied over the primary term of the contract, which is generally three to five years. Therefore, at the time any such up-front payment is received, a contract liability is recorded which represents deferred revenue. The amount of royalty revenue recognized in ~~both of~~ the three months ended ~~September~~June 30, ~~2022~~2023 and ~~2021 that was~~2022 included in the opening contract liability was $0.2 ~~million.~~million and $0.3 million, respectively. The amount of royalty revenue recognized in ~~both of~~ the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021 that was~~2022 included in the opening contract liability was ~~$0.7 million.~~$0.4 million and $0.5 million, respectively. This revenue consists of up-front lease bonus payments received under royalty contracts that are recognized over the primary term of the royalty contracts, which are generally three to five years.

The Company expects to recognize an additional $0.8 million in the remainder of ~~2022, $1.7 million in~~ 2023, ~~$0.5~~$1.5 million in 2024, ~~$0.2~~$0.3 million in 2025 and ~~a de minimis amount~~$0.1 million in both 2026 and 2027 related to the contract liability remaining at ~~September~~June 30, ~~2022.~~2023. The difference between the opening and closing balances of the Company’s contract balances results from the timing difference between the Company’s performance and the customer’s payment.

The Company has no contract assets recognized from the costs to obtain or fulfill a contract with a customer.

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NOTE 3—Inventories

Inventories are summarized as follows:


		SEPTEMBER 30 2022		DECEMBER 31 2021			JUNE 30 2023		DECEMBER 31 2022
Coal	Coal	$	20,751	$	19,352	Coal	$	17,555	$	27,927
Mining supplies	Mining supplies	41,048		34,733		Mining supplies	47,655		43,561
Total inventories	Total inventories	$	61,799	$	54,085	Total inventories	$	65,210	$	71,488

During the three and six months ended June 30, 2023, the Company recorded a $1.8 million and $4.2 million inventory impairment charge, respectively, in the line “Cost of sales” in the accompanying Unaudited Consolidated Statements of Operations as mining costs exceeded net realizable value at MLMC.

NOTE 4—Stockholders' Equity

Stock Repurchase Program: On November 10, 2021, the Company's Board of Directors approved a stock repurchase program ("2021 Stock Repurchase Program") providing for the purchase of up to $20.0 million of the Company’s outstanding Class A common stock through December 31, 2023.

The timing and amount of any repurchases under the 2021 Stock Repurchase Program are determined at the discretion of the Company's management based on a number of factors, including the availability of capital, other capital allocation alternatives,

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market conditions for the Company's Class A Common Stock and other legal and contractual restrictions. The 2021 Stock Repurchase Program does not require the Company to acquire any specific number of shares and may be modified, suspended, extended or terminated by the Company without prior notice and may be executed through open market purchases, privately negotiated transactions or otherwise. All or part of the repurchases under the 2021 Stock Repurchase Program may be implemented under a Rule 10b5-1 trading plan, which would allow repurchases under pre-set terms at times when the Company might otherwise be restricted from doing so under applicable securities laws. The Company has not repurchased any shares of common stock under the 2021 Stock Repurchase Program through ~~September~~June 30, ~~2022.~~2023.

NOTE 5—Fair Value Disclosure

Recurring Fair Value Measurements: The following table presents the Company's assets and liabilities accounted for at fair value on a recurring basis:


				Fair Value Measurements at Reporting Date Using									Fair Value Measurements at Reporting Date Using
				Quoted Prices in				Significant					Quoted Prices in				Significant
				Active Markets for		Significant Other		Unobservable					Active Markets for		Significant Other		Unobservable
				Identical Assets		Observable Inputs		Inputs					Identical Assets		Observable Inputs		Inputs
Description	Description	Date		(Level 1)		(Level 2)		(Level 3)		Description	Date		(Level 1)		(Level 2)		(Level 3)
		September 30, 2022									June 30, 2023
Assets:	Assets:									Assets:
Equity securities	Equity securities	$	14,084	$	14,084	$	—	$	—	Equity securities	$	16,641	$	16,641	$	—	$	—

		$	14,084	$	14,084	$	—	$	—		$	16,641	$	16,641	$	—	$	—

		December 31, 2021									December 31, 2022
Assets:	Assets:									Assets:
Equity securities	Equity securities	$	16,070	$	16,070	$	—	$	—	Equity securities	$	15,534	$	15,534	$	—	$	—
		$	16,070	$	16,070	$	—	$	—		$	15,534	$	15,534	$	—	$	—

Bellaire Corporation (“Bellaire”) is a non-operating subsidiary of the Company with legacy liabilities relating to closed mining operations, primarily former Eastern U.S. underground coal mining operations. Prior to ~~2021,~~2022, Bellaire contributed $5.0 million to establish a mine water treatment trust (the "Mine Water Treatment Trust") to assure the long-term treatment of post-mining discharge. Bellaire's Mine Water Treatment Trust invests in equity securities that are reported at fair value based upon quoted market prices in active markets for identical assets; therefore, they are classified as Level 1 within the fair value hierarchy. The Company recognized a ~~loss~~gain of $0.5 ~~million and $2.7 million during the three and nine months ended September 30, 2022, respectively, and a gain of less than $0.1~~ million and $1.0 million during the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2023, respectively,

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and a loss of $1.5 million and $2.1 million during the three and six months ended June 30, 2022, respectively, related to the Mine Water Treatment Trust.

Prior to ~~2021,~~2022, the Company invested $2.0 million in equity securities of a public company with a diversified portfolio of royalty producing mineral interests. The investment is reported at fair value based upon quoted market prices in active markets for identical assets; therefore, it is classified as Level 1 within the fair value hierarchy. The Company recognized a loss of $0.1 million and a de minimis gain during the three and six months ended June 30, 2023, respectively, and a loss of $0.4 million and a gain of ~~$0.2 million and $1.0~~$0.8 million during the three and ~~nine~~six months ended ~~September~~June 30, 2022, ~~respectively, and a gain of $0.4 million and $1.6 million during the three and nine months ended September 30, 2021,~~ respectively, related to the investment in these equity securities.

The ~~gains and losses related to~~change in fair value of equity securities ~~are~~is reported on the line ~~Loss (gain)~~(Gain) loss on equity securities in the Other (income) expense section of the Unaudited Condensed Consolidated Statements of Operations.

~~As discussed in Note 1, the~~Nonrecurring Fair Value Measurements: The Company recorded the estimated fair value of an office building ~~and membership units of a privately held company~~ during the second quarter of 2022. These fair value measurements were based on significant inputs not observable in the market and thus represent Level 3 measurements within the fair value measurement hierarchy. Level 3 fair market values were determined using a variety of information, including estimated future cash flows and external appraisals, and considered both the income and market approaches.

The significant assumptions used in determining the fair value of the membership units are the estimated future cash flows and the discount rate applied to the estimated future cash flows. The estimate of future cash flows is based on available historical information and forecasts provided by the privately held company that are inherently uncertain. Management determined the appropriate discount rate based on the weighted average cost of capital ("WACC"). The WACC takes into account both the

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~~after-tax cost of debt and cost of equity. A major component of the cost of equity is the current risk-free rate on twenty-year U.S. Treasury bonds as well as company specific risk and size premiums.~~

In determining the $4.1 million fair value of the office building, the Company engaged an independent real estate appraiser to appraise the property utilizing observed sales transactions for similar assets as well as consideration of an income ~~approach.~~

Prior to receiving the membership units from GRE, the Company held a $5.0 million investment in the same privately-held company. The Company previously elected to use the measurement alternative to fair value included in ASC 321, ~~Investments – Equity Securities~~, that allows investments without readily determinable fair values to be carried at cost less impairment, if any, adjusted for observable price changes in orderly transactions for the identical or similar investments. The Company determined that the receipt of the additional membership units does not represent an observable transactionapproach; therefore, it is classified as ~~defined in ASC 321. As such, the Company will add~~Level 2 within the fair value of the additional membership units of $12.8 million to the $5.0 million historical cost basis of the existing membership units, the total of which is the initial measurement of the Company’s equity method investment.

Subsequent to the receipt of the additional membership units on May 2, 2022, the Company began to account for the investment under the equity method of accounting subject to a one quarter reporting lag. The Company recorded $2.2 million, which represents its share of the privately-held company's second quarter earnings and immaterial basis difference adjustments, during the third quarter of 2022 on the "Income from equity method investee" line within the accompanying Unaudited Condensed Consolidated Statements of Operations.

hierarchy. The office building is included in Property, plant and equipment, net ~~and the investment~~ in ~~the privately-held company is included in Investment in private company equity units within~~ the accompanying Unaudited Condensed Consolidated Balance Sheets.

The Company regularly performs reviews of potential future development projects and identified certain legacy assets where future development is unlikely. As a result, the Company estimated the fair value of the assets using unobservable inputs, which are classified as Level 3 inputs. The long-lived assets, which included land, prepaid royalties and capitalized leasehold costs, were written off to zero in the third quarter of 2022 and resulted in non-cash asset impairment charges of $3.9 million in the Minerals Management segment. The impairment charges are reported on the line "Asset impairment charges" in the Unaudited Condensed Consolidated Statements of Operations.

There were no transfers into or out of Levels 1, 2 or 3 during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021.~~2022.

NOTE 6—Unconsolidated Subsidiaries

Each of the Company's wholly owned Unconsolidated Subsidiaries, within the Coal Mining and NAMining segments, meet the definition of a VIE. The Unconsolidated Subsidiaries are capitalized primarily with debt financing provided by or supported by their respective customers, and generally without recourse to ~~NACCO and NACoal.~~the Company. Although ~~NACoal~~the Company owns 100% of the equity and manages the daily operations of the Unconsolidated Subsidiaries, the Company has determined that the equity capital provided by ~~NACoal~~the Company is not sufficient to adequately finance the ongoing activities or absorb any expected losses without additional support from the customers. The customers have a controlling financial interest and have the power to direct the activities that most significantly affect the economic performance of the entities. As a result, the Company is not the primary beneficiary and therefore does not consolidate these entities' financial positions or results of operations. See Note 1 for a discussion of these entities.

The Investment in the unconsolidated subsidiaries and related tax positions totaled ~~$9.9~~$11.1 million and ~~$19.1~~$14.9 million at ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively. The Company's maximum risk of loss relating to these entities is limited to its invested capital, which was ~~$4.7~~$4.2 million and ~~$7.6~~$7.1 million at ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively. Earnings of unconsolidated operations were ~~$14.6~~$11.1 million and ~~$43.8~~$24.9 million during the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, and ~~$17.7~~$14.6 million and ~~$46.5~~$29.2 million during the three and ~~nine~~six months ended ~~September~~June 30, ~~2021.~~

The contract mining agreement between Bisti and NTEC was terminated effective September 30, 2021. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo Mine.2022, respectively.

NACoal is a party to certain guarantees related to Coyote Creek. Under certain circumstances of default or termination of Coyote Creek’s Lignite Sales Agreement (“LSA”), NACoal would be obligated for payment of a "make-whole" amount to Coyote Creek’s third-party lenders. The “make-whole” amount is based on the excess, if any, of the discounted value of the remaining scheduled debt payments over the principal amount. In addition, in the event Coyote Creek’s LSA is terminated on

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or after January 1, 2024 by Coyote Creek’s customers, NACoal is obligated to purchase Coyote Creek’s dragline and rolling stock for the then net book value of those assets. To date, no payments have been required from NACoal since the inception of these guarantees. The Company believes that the likelihood NACoal would be required to perform under the guarantees is remote, and no amounts related to these guarantees have been recorded.

NOTE 7—Contingencies

Various legal and regulatory proceedings and claims have been or may be asserted against NACCO and certain subsidiaries relating to the conduct of their businesses. These proceedings and claims are incidental to the ordinary course of business of the Company. Management believes that it has meritorious defenses and will vigorously defend the Company in these actions. Any costs that management estimates will be paid as a result of these claims are accrued when the liability is considered probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some

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circumstances, an estimate of the possible loss.

These matters are subject to inherent uncertainties, and unfavorable rulings could occur. If an unfavorable ruling were to occur, there exists the possibility of an adverse impact on the Company’s financial position, results of operations and cash flows of the period in which the ruling occurs, or in future periods.

NOTE 8—Business Segments

The Company’s operating segments are: (i) Coal Mining, (ii) NAMining and (iii) Minerals Management. The Company determines its reportable segments by first identifying its operating segments, and then by assessing whether any components of these segments constitute a business for which discrete financial information is available and where segment management regularly reviews the operating results of that component. The Company’s Chief Operating Decision Maker utilizes operating profit to evaluate segment performance and allocate resources.

The Company has items not directly attributable to a reportable segment that are not included as part of the measurement of segment operating profit, which include primarily administrative costs related to public company reporting requirements at the parent company and the financial results of Mitigation Resources and Bellaire. Mitigation Resources generates and sells stream and wetland mitigation credits (known as mitigation banking) and provides services to those engaged in permittee-responsible stream and wetland mitigation. Bellaire manages the Company’s long-term liabilities related to former Eastern U.S. underground mining activities.

All financial statement line items below operating profit (other income including interest expense and interest income, the (benefit) provision for income taxes and net income) are presented and discussed within this Form 10-Q on a consolidated basis.

The following table presents revenues, operating profit (loss), expenditures for property, plant and equipment and acquisition of mineral interests and depreciation, depletion and amortization expense:


	THREE MONTHS ENDED				SIX MONTHS ENDED
	JUNE 30				JUNE 30
	2023		2022		2023		2022
Revenues
Coal Mining	$	26,343	$	26,602	$	46,996	$	47,564
NAMining	21,716		22,814		42,349		44,218
Minerals Management	9,171		11,962		17,456		24,716
Unallocated Items	4,628		617		5,819		809
Eliminations	(508)		(626)		(1,129)		(915)
Total	$	61,350	$	61,369	$	111,491	$	116,392

Operating profit (loss)
Coal Mining	$	(4,675)	$	21,175	$	(4,362)	$	28,527
NAMining	2,214		1,257		3,044		2,528
Minerals Management	7,289		13,073		13,333		24,701
Unallocated Items	(3,065)		(5,952)		(8,418)		(11,391)
Eliminations	(13)		130		(33)		262
Total	$	1,750	$	29,683	$	3,564	$	44,627

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As discussed in Note 1, the Company retrospectively changed its computation of segment operating profit to reclassify the results of Caddo Creek and Demery from the Coal Mining segment into the NAMining segment. See Note 1 for additional discussion of the Company's reportable segments. The following tables present revenue, operating profit, capital expenditures and depreciation expense:

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
2022 2021 2022 2021
Revenues
Coal Mining $ 22,599 $ 20,946 $ 70,163 $ 63,577
NAMining 22,962 20,429 67,180 58,228
Minerals Management 16,172 10,607 40,888 21,715
Unallocated Items 1,092 1,594 1,901 2,647
Eliminations (1,032) (1,834) (1,947) (3,424)
Total $ 61,793 $ 51,742 $ 178,185 $ 142,743
Operating profit (loss)
Coal Mining $ 6,089 $ 21,985 $ 34,616 $ 37,769
NAMining (210) 1,448 2,318 3,803
Minerals Management 10,616 9,454 35,317 17,862
Unallocated Items (6,780) (5,170) (18,171) (14,738)
Eliminations 103 (125) 365 (104)
Total $ 9,818 $ 27,592 $ 54,445 $ 44,592


						THREE MONTHS ENDED						SIX MONTHS ENDED
						JUNE 30						JUNE 30
												2023		2022		2023		2022
Expenditures for property, plant and equipment and acquisition of mineral interests	Expenditures for property, plant and equipment and acquisition of mineral interests										Expenditures for property, plant and equipment and acquisition of mineral interests
Coal Mining	Coal Mining	$	3,141	$	5,646		$	11,141	$	10,378	Coal Mining	$	1,032	$	6,280	$	3,718	$	8,000
NAMining	NAMining	604		13,309			8,985		19,127		NAMining	4,507		6,561		8,930		8,381
Minerals Management	Minerals Management	11,397		450			12,346		5,948		Minerals Management	638		116		982		949
Unallocated Items	Unallocated Items	1,944		2			9,532		81		Unallocated Items	79		7,312		505		7,588
Total	Total	$	17,086	$	19,407		$	42,004	$	35,534	Total	$	6,256	$	20,269	$	14,135	$	24,918

Depreciation, depletion and amortization	Depreciation, depletion and amortization										Depreciation, depletion and amortization
Coal Mining	Coal Mining	$	4,257	$	4,306		$	12,683	$	12,534	Coal Mining	$	4,348	$	4,388	$	8,588	$	8,426
NAMining	NAMining	1,585		1,031			4,545		2,966		NAMining	1,855		1,493		3,741		2,960
Minerals Management	Minerals Management	660		423			1,781		1,392		Minerals Management	749		543		1,560		1,121
Unallocated Items	Unallocated Items	67		36			175		106		Unallocated Items	138		64		220		108
Total	Total	$	6,569	$	5,796		$	19,184	$	16,998	Total	$	7,090	$	6,488	$	14,109	$	12,615

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

(Amounts in thousands, except as noted and per share data)

Management's Discussion and Analysis of Financial Condition and Results of Operations contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These statements are based upon management's current expectations and are subject to various uncertainties and changes in circumstances. Important factors that could cause actual results to differ materially from those described in these forward-looking statements are set forth below under the heading “Forward-Looking Statements."

Management's Discussion and Analysis of Financial Condition and Results of Operations include NACCO Industries, Inc.® (“NACCO”) and its wholly owned subsidiaries (collectively, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines for power generation companies. The NAMining segment is a trusted mining partner for producers of aggregates, activated carbon, lithium and other industrial minerals. The Minerals Management segment, which includes the Catapult Mineral Partners ("Catapult") business, acquires and promotes the development of mineral interests. Mitigation Resources of North America® (“("Mitigation ~~Resources”~~Resources") provides stream and wetland mitigation solutions.

The Company has items not directly attributable to a reportable segment that are not included as part of the measurement of segment operating profit, which primarily includes administrative costs related to public company reporting requirements at the parent company and the financial results of Mitigation Resources and Bellaire Corporation ("Bellaire"). Bellaire manages the Company’s long-term liabilities related to former Eastern U.S. underground mining activities.

All financial statement line items below operating profit (other income, including interest expense and interest income, the (benefit) provision for income taxes and net income) are presented and discussed within this Form 10-Q on a consolidated basis.

The Company’s operating segments are further described below:

Coal Mining Segment

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million, as agreed to under the termination and release of claims agreement between Falkirk and GRE. See Note 5 for further discussion on fair value. Prior to receiving the membership units from GRE, the Company held a $5.0 million investment in the same privately-held company carried at cost, less impairment. Subsequent to the receipt of the additional membership units on May 2, 2022, the Company began to account for the investment under the equity method of accounting subject to a one quarter reporting lag.

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reclamation, and directly or indirectly provide all of the capital required to build and operate the mine. This contract structure eliminates exposure to spot coal market price fluctuations while providing income and cash flow with minimal capital investment. Other than at Coyote Creek, debt financing provided by or supported by the customers is without recourse to ~~NACCO and NACoal.~~the Company. See Note 6 to the Unaudited Condensed Consolidated Financial Statements for further discussion of Coyote Creek's guarantees.

Coteau, Coyote Creek, Falkirk and Sabine ~~each~~ meet the definition of a variable interest entity ("VIE"). In each case, NACCO is not the primary beneficiary of the VIE as it does not exercise financial control; therefore, NACCO does not consolidate the results of these operations within its financial statements. Instead, these contracts are accounted for as equity method investments. The income before income taxes associated with these VIEs is reported as Earnings of unconsolidated operations on the Unaudited Condensed Consolidated Statements of Operations and the Company’s investment is reported on the line Investments in unconsolidated subsidiaries in the Unaudited Condensed Consolidated Balance Sheets. The mines that meet the definition of a VIE are referred to collectively as the “Unconsolidated Subsidiaries.” For tax purposes, the Unconsolidated Subsidiaries are included within the NACCO consolidated U.S. tax return; therefore, the Income tax (benefit) provision line on the Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. See Note 6 to the Unaudited Condensed Consolidated Financial Statements for further information on the Unconsolidated Subsidiaries.

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NAMining Segment

Minerals Management Segment

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~~The Minerals Management segment owns royalty interests, mineral interests, nonparticipating royalty interests, and overriding royalty interests. The Company may own more~~Government Regulation Update

Other than ~~one type of mineral and royalty interest~~as described in the same tract of land. For example, where the Company owns an overriding royalty interest in a lease on the same tract of land in which it owns a mineral interest, the overriding royalty interest in that tract will relatefollowing section, there were no significant changes to the ~~same gross acres~~Company’s government regulation matters subsequent to December 31, 2022. Information regarding the Company’s government regulation matters is outlined in Part I, Item 1. “Business” in its Annual Report on Form 10-K for the year ended December 31, 2022.

Greenhouse Gas (“GHG”) Emissions

In July 2019, the U.S. Environmental Protection Agency (the “EPA”) finalized a rule that repealed the Clean Power Plan (“CPP”) that had been finalized in 2015 and established new regulations addressing GHG emissions from existing coal-fueled electric generation units, referred to as the ~~mineral interest~~Affordable Clean Energy (“ACE”) rule. The ACE rule developed emission guidelines that states must use when developing plans to regulate GHG emissions from existing coal-fueled electric generating units (“EGUs”). In response to challenges brought by environmental groups and certain states, the U.S. Court of Appeals for the District of Columbia Circuit (the “D.C. Circuit Court”) vacated the ACE rule, including its repeal of the CPP, in January 2021 and remanded the rule to the EPA for further action. On June 30, 2022, the U.S. Supreme Court issued an opinion reversing the D.C. Circuit Court's decision, and finding that ~~tract.~~the EPA exceeded its statutory authority when the EPA set emission requirements in the CPP based on generation shifting. On May 11, 2023, the EPA proposed a new rule imposing limits on GHG emissions from existing coal and new natural-gas electric generating units, which could compel such facilities to install additional pollution controls or shut down.

The ~~Minerals Management segment~~proposed rule includes guidelines for carbon dioxide ("CO2") emissions from existing EGUs with a proposed compliance date of January 1, 2030. For coal-fired steam EGUs that plan to operate past January 1, 2040, the EPA is proposing a best system of emissions reduction ("BSER") of carbon capture and sequestration/storage ("CCS") with 90 percent capture of CO2 at the stack. For coal-fired steam EGUs that will ~~benefit from~~permanently cease operations after December 31, 2031, but before January 1, 2040, the ~~continued development~~EPA is proposing a BSER of ~~its mineral properties without~~40 percent natural gas co-firing on a heat input basis. Coal-fired steam EGUs that will permanently cease operations between December 31, 2031 and January 1, 2035, will be subject to an annual capacity factor limit, and for units that will permanently cease operations before January 1, 2032, the ~~need for investment~~EPA is proposing a BSER of additional capital once mineral and royalty interests have been acquired. The Minerals Management segment does not have any investments under which it would be required to bear the cost of exploration, production or development.

routine

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methods of operation and maintenance that maintain current emission rates. Each of the EGUs supplied by the Company would be subject to these proposed requirements.

Additionally, the proposed rule contains other actions, including revised new source performance standards for GHG emissions from new and reconstructed fossil fuel-fired steam EGUs that undertake a large modification. These new rules may raise the cost of fossil fuel generated energy, making coal-fired power plants less competitive, and/or result in early closure which could have an adverse impact on demand for coal and ultimately result in the early closure of the mines servicing these plants, including closure of the Company's coal mines. Any such closure of the Company's mines could have a material adverse effect on the Company’s business, financial condition and results of operations.

Clean Air Act ("CAA")

The process of burning coal can cause many compounds and impurities in the coal to be released into the air, including sulfur dioxide, nitrogen oxides (“NOx”), mercury, particulates and other matter. The CAA and the corresponding state laws that extensively regulate the emissions of materials into the air affect coal mining operations both directly and indirectly. Direct impacts on coal mining operations occur through CAA permitting requirements and/or emission control requirements relating to air contaminants, especially particulate matter. Indirect impacts on coal mining operations occur through regulation of the air emissions of sulfur dioxide, nitrogen oxides, mercury, particulate matter and other compounds emitted by coal-fired power plants. The EPA has promulgated or proposed regulations that impose tighter emission restrictions in a number of areas, some of which are currently subject to litigation. The general effect of tighter restrictions is to reduce demand for coal. Ongoing reduction in coal’s share of the capacity for power generation could have a material adverse effect on the Company’s business, financial condition and results of operations.

The CAA requires the EPA to review national ambient air quality standards (“NAAQS”) every five years to determine whether revisions to current standards is appropriate. In addition, states are required to submit to the EPA revisions to their state implementation plans ("SIPs") that demonstrate the manner in which the states will attain NAAQS every time a NAAQS is issued or revised by the EPA. The EPA has adopted NAAQS for several pollutants, which continue to be reviewed periodically for revisions. When the EPA adopts new, more stringent NAAQS for a pollutant, some states have to change their existing SIPs. If a state fails to revise its SIP and obtain EPA approval, the EPA may adopt regulations to affect the revision. Coal mining operations and coal-fired power plants that emit particulate matter or other specified material are, therefore, affected by changes in the SIPs. Through this process over the last few years, the EPA has reduced the NAAQS for particulate matter, ozone and nitrogen oxides. The Company's coal mining operations and power generation customers may be directly affected when the revisions to the SIPs are made and incorporate new NAAQS for sulfur dioxide, nitrogen oxides, ozone and particulate matter. In March 2019, the EPA published a final rule that retains the current primary (health-based) NAAQS for sulfur oxides ("SOx") without revision. The current primary standard is set at a level of 75 parts per billion, as the 99th percentile of daily maximum 1-hour sulfur dioxide concentrations, averaged over 3 years. On January 6, 2023, the EPA proposed to lower the level of the particulate matter. If enacted as proposed, this rule would require fossil fuel generating units to install additional emission reducing technologies, which will ultimately increase the cost of fossil fuel generated energy or cause potential EGU retirements.

In 2011, the EPA finalized the Cross-State Air Pollution Rule ("CSAPR") to address interstate transport of pollutants. This affects states in the eastern half of the U.S. and Texas. This rule imposes additional emission restrictions on coal-fired power plants to attain ozone and fine particulate NAAQS. The EPA began implementation of the rule in 2015, when Phase I emission reductions in sulfur dioxide and nitrogen dioxide became effective. In 2019, certain states submitted SIPs to the EPA in response to the 2015 ozone standard reduction. The SIPs were rejected by the EPA on February 13, 2023. On March 15, 2023, the EPA signed the Federal Good Neighbor Plan for the 2015 Ozone NAAQS (“Final FIP”), which provides federal implementation plan ("FIP") requirements for 23 states, including Mississippi where MLMC operates, and requires significant reductions of NOx from power plants and industrial sources in these states. The rule includes emission limits for NOx for fossil fuel-fired EGUs and a “backstop daily emissions rate” for large coal-fired EGUs if they exceed specified limits.

The EPA’s action to deny the SIPs was challenged in various courts, including the 5th Circuit Court of Appeals (the “Fifth Circuit”). The Fifth Circuit issued a stay of the SIP rejection in Texas, Louisiana, and Mississippi which prevents the Final FIP from going into effect pending the outcome of the litigation challenges to the Final FIP. As a result, the EPA is currently writing an interim FIP for states where a stay has been granted that will likely attempt to require these states to return to the previously approved NOx trading program and emission caps. Should the Final FIP be fully implemented, the rule could influence the closure of some coal-fired EGUs that have not installed selective catalytic reduction technologies, potentially including the EGU supplied by MLMC. Should the interim FIP be implemented, it could result in an increase in the cost to comply with emission limits as the pool of available NOx emission credits will be reduced.

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Under the CAA, the EPA also adopts national emission standards for hazardous air pollutants. In December 2011, the EPA adopted a final rule called the Mercury and Air Toxics Standard (“MATS”), which applies to new and existing coal-fired EGUs. This rule requires mercury emission reductions in mercury-containing particulate matter.

In 2020, the EPA issued a final rule reversing a prior finding and determined that it is not “appropriate and necessary” under the CAA to regulate hazardous air pollutant emissions from coal-fired power plants. On February 9, 2022 the EPA proposed a rule to revoke the 2020 finding and to reaffirm the agency’s 2016 finding that it remained “appropriate and necessary” to regulate mercury-containing particulate matter. The EPA finalized the 2022 proposed rule on March 6, 2023, revoking the 2020 finding and concluding that it is appropriate and necessary to regulate mercury-containing particulate matter. In April 2023, the EPA proposed corresponding revisions to the MATS rule. These revisions would remove the mercury emission limit for lignite-fired EGUs and require particulate emission reductions for all coal-fired EGUs. If enacted as proposed, this rule could influence the closure of additional coal-fired EGUs, potentially including all of the EGUs supplied by the Company.

The Company's power generation customers must incur substantial costs to control emissions to meet all of the CAA requirements, including the requirements under MATS and the EPA's regional haze program. These costs raise the price of coal-generated electricity, making coal-fired power less competitive with other sources of electricity, thereby reducing demand for coal. If the Company's customers cannot offset the cost to control certain regulated pollutant emissions by lowering costs or if the Company's customers elect to close coal-fired units, the Company’s business, financial condition and results of operations could be materially adversely affected.

Clean Water Act ("CWA")

CWA affects coal mining operations by establishing in-stream water quality standards and treatment standards for waste water discharge, including from coal mines. These federal and state requirements could require more costly water treatment and could materially adversely affect the Company’s business, financial condition and results of operations.

The Company believes it has obtained all permits required under the CWA and corresponding state laws and is in compliance with such permits. In many instances, mining operations require securing CWA authorization or a permit from the U.S. Army Corps of Engineers for operations in waters of the United States ("WOTUS.") The Supreme Court of the United States heard the Sackett vs. EPA case in October 2022, which considered whether certain wetlands constitute WOTUS. In the meantime, in January 2023, the EPA published a new rule that redefines WOTUS that relies on the expansive significant nexus test. The new definition expanded the scope of federal jurisdiction over land and water features which could cause some of the Company's operations to incur additional costs to mitigate streams and wetlands. The new WOTUS definition was ultimately stayed in 24 states, including Mississippi, North Dakota and Texas, and on May 25, 2023, the Supreme Court issued its Sackett vs. EPA ruling that defines WOTUS as “a relatively permanent body of water connected to traditional interstate navigable waters” with a “continuous surface connection with that water, making it difficult to determine where the ‘water’ ends and the ‘wetland’ begins.” The Supreme Court decision rejected the “significant nexus” test relied upon by the EPA in its new 2023 WOTUS rule.

As a result, the EPA and the Army Corps of Engineers are authoring a revised definition of WOTUS. This has made securing CWA permits more challenging due to uncertainty.

Bellaire is treating mine water drainage from coal refuse piles associated with former underground coal mines in Ohio and Pennsylvania. Bellaire anticipates that it will need to continue these activities indefinitely. Bellaire was notified by the Pennsylvania Department of Environmental Protection during 2004 that in order to obtain renewal of a permit, Bellaire would be required to establish a mine water treatment trust. See Note 7 and Note 9 to the Consolidated Financial Statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 2022 filed on March 15, 2023 for further information on Bellaire.

Resource Conservation and Recovery Act ("RCRA")

RCRA affects coal mining operations by establishing requirements for the treatment, storage and disposal of wastes, including hazardous wastes. Coal mine wastes, such as overburden and coal cleaning wastes, currently are exempted from hazardous waste management. In 2020, the EPA finalized changes to the coal combustion residual ("CCR") rule that classified all clay-lined surface impoundments that receive CCR as unlined, which triggered a pond closure date of April 2021 for impoundments that failed the aquifer location restriction. The EPA also established alternative deadlines to cease receipt of waste to include new site-specific alternatives due to lack of capacity with a deadline to initiate closure no later than October 15, 2023 and a new site-specific alternative due to permanent cessation of coal-fired boilers with two deadlines to complete closure: (a) no later than October 17, 2023 for surface impoundments 40 acres or smaller; and (b) October 17, 2028 for surface impoundments larger than 40 acres. These rules may raise the cost for CCR disposal at coal-fired power plants, making them less competitive, and/or result in early closure which could have an adverse impact on demand for coal and ultimately result in the early closure

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of the mines servicing these plants, including closure of the Company's mines. Any such closure of the Company's mines could have a material adverse effect on the Company’s business, financial condition and results of operations.

In compliance with the regulations, the owner of ~~royalty~~the Coal Creek Station power plant, Falkirk’s customer, submitted a Part B application to the EPA in 2020 asserting a unit complied with the CCR rules. In the first quarter of 2023, the EPA proposed to deny the owner’s application. The owner and ~~mineral interests,~~other parties have submitted additional information and comments supporting the owner’s position. If the EPA ultimately denies the owner’s application, a new liner may need to be installed or new waste management processes and/or units may need to be constructed. Accordingly, it is possible that a denial by the EPA could require a temporary unit shut down. Any temporary unit shut down could result in a temporary suspension of operations at Coal Creek Station. To minimize any impact to operations, Coal Creek Station is moving forward with plans to dry CCR materials produced by the plant, reducing the need to utilize the lined area in question. Falkirk is the sole supplier of lignite coal to Coal Creek Station. Any suspension of operations at Coal Creek Station would eliminate the need for lignite coal during the suspension period. Any such suspension of operations at Coal Creek Station or any of the power plants supplied by the Company's mines could have a material adverse effect on the Company’s ~~access to information concerning activity~~business, financial condition and ~~operations~~results of ~~its royalty and mineral interests is limited. The Company does not have information~~operations.

In May 2023, the EPA published proposed regulations that would impose federal regulatory requirements for previously exempt inactive CCR surface impoundments at inactive facilities (legacy CCR surface impoundments). If finalized as proposed, it could increase the regulatory cost of compliance for the Company's customers thereby increasing the cost of power which could materially adversely affect the Company’s business, financial condition and results of operations.

The EPA rule exempts CCRs beneficially used at mine sites and reserves any regulation thereof to the Office of Surface Mining Reclamation and Enforcement ("OSMRE"). The OSMRE suspended all rulemaking actions on CCRs, but could re-initiate them in the future. The outcome of these rulemakings, and any subsequent actions by the EPA and OSMRE, could impact those Company operations that beneficially use CCRs. If the Company were unable to beneficially use CCRs, its revenues for handling CCRs from its customers may decrease and its costs may increase due to the purchase of alternative materials for beneficial uses.

National Environmental Policy Act ("NEPA")

NEPA requires federal agencies to review the environmental impacts of their decisions and issue either an environmental assessment or an environmental impact statement. There are certain actions associated with surface coal mining that may trigger these types of assessments by federal agencies. When a NEPA action is required, the Company provides the required information to the appropriate federal agency to enable it to complete the required study. Historically, this process has been lengthy and may take several years to complete. In January 2023, the White House Council on Environmental Quality ("CEQ") issued interim guidance that instructs federal agencies to quantify GHG emissions for each alternative and use the social cost of greenhouse gasses to calculate a monetary metric associated with the proposed actions’ climate effects. The NEPA and interim guidance could adversely affect the Company’s ability to secure necessary permits.

On April 21, 2023, President Biden signed a new executive order focused on incorporating environmental justice considerations into federal decision-making. The executive order created a new White House Office of Environmental Justice, and directed all federal agencies to make environmental justice a central part of each agency’s mission by publishing an environmental justice strategic plan for the agency. Additionally, the order requires agencies conducting NEPA reviews to assess direct, indirect and cumulative impacts on environmental justice communities in their analyses, to consider best available science and information on disparate health impacts related to exposure to environmental hazards and provide opportunities for meaningful engagement with environmental justice communities during the environmental review process. It remains to be ~~available~~seen how federal agencies will undertake to comply with these new requirements addressing environmental justice considerations, but the development and application of the new requirements may result in permit uncertainty and delays for activities that require federal approvals.

On June 3, 2023, President Biden signed the Fiscal Responsibility Act of 2023 into law, which included certain provisions collectively known as the Builder Act. These Builder Act includes amendments to NEPA codify past regulatory reforms including narrowing what qualifies as a ~~company with oil~~“major federal action,” limiting the scope of NEPA review to “reasonably foreseeable environmental effects,” narrowing consideration of cumulative effects, directing agencies to only consider technically and ~~natural gas operations because detailed information is not generally available~~economically feasible reasonable alternatives and providing page limits and timelines for environmental impact statements and environmental assessments. It remains to ~~owners of royalty and mineral interests.~~be seen how the changes enacted by Congress will impact site level NEPA analysis.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Refer to the discussion of the Company's Critical Accounting Policies and Estimates as disclosed on pages 4552 through 4654 in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2021.~~2022. The Company's Critical Accounting Policies and Estimates have not materially changed since December 31, ~~2021.~~2022.

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CONSOLIDATED FINANCIAL SUMMARY

The results of operations for NACCO were as follows for the three and ~~nine~~six months ended ~~September~~June 30:


		THREE MONTHS						NINE MONTHS							THREE MONTHS						SIX MONTHS
		2022			2021			2022			2021				2023			2022			2023			2022
Revenues:	Revenues:													Revenues:
Coal Mining	Coal Mining	$	22,599		$	20,946		$	70,163		$	63,577		Coal Mining	$	26,343		$	26,602		$	46,996		$	47,564
NAMining	NAMining	22,962			20,429			67,180			58,228			NAMining	21,716			22,814			42,349			44,218
Minerals Management	Minerals Management	16,172			10,607			40,888			21,715			Minerals Management	9,171			11,962			17,456			24,716
Unallocated Items	Unallocated Items	1,092			1,594			1,901			2,647			Unallocated Items	4,628			617			5,819			809
Eliminations	Eliminations	(1,032)			(1,834)			(1,947)			(3,424)			Eliminations	(508)			(626)			(1,129)			(915)
Total revenue	Total revenue	$	61,793		$	51,742		$	178,185		$	142,743		Total revenue	$	61,350		$	61,369		$	111,491		$	116,392
Operating profit (loss):	Operating profit (loss):													Operating profit (loss):
Coal Mining	Coal Mining	$	6,089		$	21,985		$	34,616		$	37,769		Coal Mining	$	(4,675)		$	21,175		$	(4,362)		$	28,527
NAMining	NAMining	(210)			1,448			2,318			3,803			NAMining	2,214			1,257			3,044			2,528
Minerals Management	Minerals Management	10,616			9,454			35,317			17,862			Minerals Management	7,289			13,073			13,333			24,701
Unallocated Items	Unallocated Items	(6,780)			(5,170)			(18,171)			(14,738)			Unallocated Items	(3,065)			(5,952)			(8,418)			(11,391)
Eliminations	Eliminations	103			(125)			365			(104)			Eliminations	(13)			130			(33)			262
Total operating profit	Total operating profit	9,818			27,592			54,445			44,592			Total operating profit	1,750			29,683			3,564			44,627
Interest expense	Interest expense	486			493			1,495			1,208			Interest expense	572			496			1,117			1,009
Interest income	Interest income	(352)			(101)			(692)			(321)			Interest income	(1,714)			(195)			(2,869)			(340)
Closed mine obligations	Closed mine obligations	398			372			1,155			1,119			Closed mine obligations	433			377			842			757
Loss (gain) on equity securities		316			(445)			1,676			(2,530)
Income from equity method investee		(2,156)			—			(2,156)			—
(Gain) loss on equity securities														(Gain) loss on equity securities	(421)			1,878			(1,049)			1,360

Other contract termination settlements	Other contract termination settlements	—			—			(16,882)			—			Other contract termination settlements	—			(16,882)			—			(16,882)
Other, net	Other, net	(354)			(161)			(1,648)			(418)			Other, net	(377)			(1,064)			(2,102)			(1,294)
Other (income) expense, net		(1,662)			158			(17,052)			(942)
Income before income tax provision		11,480			27,434			71,497			45,534
Income tax provision		866			2,597			11,121			5,231
Other income, net														Other income, net	(1,507)			(15,390)			(4,061)			(15,390)
Income before income tax provision (benefit)														Income before income tax provision (benefit)	3,257			45,073			7,625			60,017
Income tax provision (benefit)														Income tax provision (benefit)	737			7,893			(587)			10,255
Net income	Net income	$	10,614		$	24,837		$	60,376		$	40,303		Net income	$	2,520		$	37,180		$	8,212		$	49,762

Effective income tax rate	Effective income tax rate	7.5		%	9.5		%	15.6		%	11.5		%	Effective income tax rate	22.6		%	17.5		%	(7.7)		%	17.1		%

The components of the change in revenues and operating profit are discussed below in "Segment Results."

~~Third~~Second Quarter of 2023 Compared with Second Quarter of 2022, and First Six Months of 2023 Compared with ~~Third Quarter of 2021, and~~ First ~~Nine~~Six Months of 2022 ~~Compared with First Nine Months of 2021~~

Other ~~income,~~(income) expense, net

During the second quarter of 2022, GRE transferred ownership of an office building with an estimated fair value of $4.1 million

and conveyed membership units in ~~a privately-held company~~Midwest AgEnergy, LLC (“MAG”) with an estimated fair value of $12.8 ~~million, as agreed to under~~

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~~the termination and release of claims agreement between Falkirk and GRE.~~million. The Company recognized a gain of $16.9 million on the "Other contract termination settlements" line within the accompanying Unaudited Condensed Consolidated Statements of Operations during the second quarter of 2022 as a result of the transactions with GRE.

~~Subsequent to the receipt of the additional membership units on May 2,~~On December 1, 2022, the Company ~~began~~transferred its ownership interest in MAG to ~~account for the investment under the equity method of accounting subject to a one quarter reporting lag.~~HLCP Ethanol Holdco, LLC. The Company ~~recorded $2.2~~received a payment of $1.2 million in the first six months of 2023 in connection with a post-closing purchase price adjustment, which ~~represents its share of the privately-held company's second quarter earnings and immaterial basis difference adjustments, during the third quarter of 2022~~is included on the ~~"Income from equity method investee"~~ line "Other, net" within the accompanying Unaudited ~~Condensed~~ Consolidated Statements of Operations. See Note 1 to the Unaudited Condensed Consolidated Financial Statements for further discussion of MAG.

~~Loss (gain)~~

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Interest income increased in the second quarter of 2023 and the first six months of 2023 compared with the respective 2022 periods primarily due to a higher average invested cash balance as well as an increase in interest rates.

(Gain) loss on equity securities represents changes in the market price of invested assets reported at fair value. The change in the ~~third~~second quarter of ~~2022~~2023 and the first ~~nine~~six months of ~~2022~~2023 compared with the respective ~~2021~~2022 periods was due to fluctuations in the market prices of the exchange-traded equity securities.

See Note 5 to the Unaudited Condensed Consolidated Financial Statements for further discussion of ~~the Other contract termination settlements, equity method investment and~~ equity securities.

Income Taxes

The Company files income tax returns in the U.S. federal jurisdiction, and in various state and foreign jurisdictions. Since 2021, the Company has participated in a voluntary program with the IRS called Compliance Assurance Process (“CAP”). The objective of CAP is to contemporaneously work with the IRS to achieve federal tax compliance and resolve all or most of the issues prior to filing of the tax return. The Company recognized a ~~$1.2 million discrete tax benefit during the third quarter of 2022, primarily due to the IRS concluding its examination of tax years 2013-2016.~~

The Company evaluates and updates its estimated annual effective income tax rate on a quarterly basis based on current and forecasted operating results and tax laws. Consequently, based upon the mix and timing of actual earnings compared to projections of earnings between entities that benefit from percentage depletion and those that do not, the effective tax rate may vary quarterly. The ~~estimated annual effective~~benefit of percentage depletion is not directly related to the amount of consolidated pre-tax income recorded in a period. Accordingly, as a result of the significant reduction in 2023 forecasted income before income tax ~~rate differs from~~compared with 2022, the ~~U.S. federal statutory rate due, in part, to~~proportional effect of the benefit from percentage ~~depletion. Changes in the estimated annual effective tax rate result in a cumulative adjustment. The increase in~~depletion on the effective income tax rate results in a negative forecasted effective tax rate for 2023. Each quarter, the nine months ended September 30, 2022 compared with the 2021 period reflects the impact of a higher forecast of full-year pre-tax income in 2022 compared with the prior year, including the $30.9 million gain recognized as a resultCompany updates its estimate of the ~~settlement under~~annual effective tax rate and makes a cumulative adjustment if the ~~termination and release of claims agreement with GRE.~~estimated annual tax rate has changed.

The Inflation Reduction Act of 2022 (the “Act”) was signed into U.S. law on August 16, 2022. The Act includes various tax provisions, including an excise tax on stock repurchases and a corporate alternative minimum tax that generally applies to U.S. corporations with average adjusted financial statement income over a three-year period in excess of $1 billion. The Company does not expect the Act to materially impact its financial statements. The enactment of additional tax reform legislation could adversely impact the Company’s financial position and results of operations. Legislation or other changes in U.S. tax law, including the elimination of certain U.S. federal income tax benefits currently available to coal mining and oil and gas exploration and development companies, could increase the Company’s tax liability and adversely affect its after-tax profitability.

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LIQUIDITY AND CAPITAL RESOURCES OF NACCO

Cash Flows

The following tables detail NACCO's changes in cash flow for the ~~nine~~six months ended ~~September~~June 30:


		2022		2021		Change			2023		2022		Change
Operating activities:	Operating activities:							Operating activities:

Net cash provided by operating activities	Net cash provided by operating activities	$	54,929	$	67,794	$	(12,865)	Net cash provided by operating activities	$	23,287	$	40,481	$	(17,194)

Investing activities:	Investing activities:							Investing activities:
Expenditures for property, plant and equipment and acquisition of mineral interests	Expenditures for property, plant and equipment and acquisition of mineral interests	(42,004)		(35,534)		(6,470)		Expenditures for property, plant and equipment and acquisition of mineral interests	(14,135)		(24,918)		10,783
Other	Other	2,766		495		2,271		Other	1,436		2,802		(1,366)
Net cash used for investing activities	Net cash used for investing activities	(39,238)		(35,039)		(4,199)		Net cash used for investing activities	(12,699)		(22,116)		9,417
Cash flow before financing activities	Cash flow before financing activities	$	15,691	$	32,755	$	(17,064)	Cash flow before financing activities	$	10,588	$	18,365	$	(7,777)

The ~~$12.9~~$17.2 million change in net cash provided by operating activities was primarily due to a ~~net unfavorable change in working capital, mainly attributable to an increase in Federal income tax receivable in the first nine months of 2022 compared with a~~$41.6 million decrease in ~~the first nine months of 2021. The $20.1 million increase in~~ net

income ~~was~~partially offset by non-cash adjustments recognized during the first ~~nine~~six months of 2022, including $16.9 million related to the termination and release of claims agreement between Falkirk and GRE. An unfavorable change in working capital also contributed to the reduction in net cash provided by operating activities.


		2022		2021		Change			2023		2022		Change
Financing activities:	Financing activities:							Financing activities:
Net reductions to long-term debt and revolving credit agreement	Net reductions to long-term debt and revolving credit agreement	$	(4,454)	$	(29,498)	$	25,044	Net reductions to long-term debt and revolving credit agreement	$	(1,130)	$	(4,291)	$	3,161
Cash dividends paid	Cash dividends paid	(4,488)		(4,200)		(288)		Cash dividends paid	(3,190)		(2,966)		(224)

Net cash used for financing activities	Net cash used for financing activities	$	(8,942)	$	(33,698)	$	24,756	Net cash used for financing activities	$	(4,320)	$	(7,257)	$	2,937

The change in net cash used for financing activities was primarily due to fewer repayments ~~as a result of a reduction in borrowings under the Company’s revolving line of credit~~ during the first ~~nine~~six months of ~~2022~~2023 compared with the first ~~nine~~six months of ~~2021.~~2022.

Financing Activities

Financing arrangements are obtained and maintained at the NACCO Natural Resources level. NACCO Natural Resources is the Company's holding Company for NACoal, ~~level. NACoal~~NAMining, Catapult and Mitigation Resources. NACCO Natural Resources has a secured revolving line of credit of up to $150.0 million (the ~~“NACoal Facility”~~“Facility”) that expires in November 2025. There were no borrowings outstanding under the ~~NACoal~~ Facility at ~~September~~June 30, ~~2022.~~2023. At ~~September~~June 30, ~~2022,~~2023, the excess availability under the ~~NACoal~~ Facility was ~~$119.3~~$117.2 million, which reflects a reduction for outstanding letters of credit of ~~$30.7~~$32.8 million.

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NACCO has not guaranteed any borrowings of ~~NACoal.~~NACCO Natural Resources. The borrowing agreements at ~~NACoal~~NACCO Natural Resources allow for the payment to NACCO of dividends and advances under certain circumstances. Dividends (to the extent permitted by ~~NACoal's borrowing agreement)~~the Facility) and management fees are the primary sources of cash for NACCO and enable the Company to pay dividends to ~~stockholders.~~stockholders and repurchase shares.

The ~~NACoal~~ Facility has performance-based pricing, which sets interest rates based upon ~~NACoal~~NACCO Natural Resources achieving various levels of debt to EBITDA ratios, as defined in the ~~NACoal~~ Facility. Borrowings bear interest at a floating rate plus a margin based on the level of debt to EBITDA ratio achieved. The applicable margins, effective ~~September~~June 30, ~~2022,~~2023, for base rate and LIBOR loans were ~~1.25%~~1.23% and ~~2.25%~~2.23%, respectively. The ~~NACoal~~ Facility has a commitment fee which is based upon achieving various levels of debt to EBITDA ratios. The commitment fee was ~~0.35%~~0.34% on the unused commitment at ~~September~~June 30, ~~2022. During the nine months ended September 30, 2022, the average borrowing under the NACoal Facility was $2.6 million and the weighted-average annual interest rate was 3.8%.~~2023.

The ~~NACoal~~ Facility contains restrictive covenants, which require, among other things, ~~NACoal~~NACCO Natural Resources to maintain a maximum net debt to EBITDA ratio of 2.75 to 1.00 and an interest coverage ratio of not less than 4.00 to 1.00. The ~~NACoal~~ Facility provides the ability to make loans, dividends and advances to NACCO, with some restrictions based on maintaining a maximum debt to

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EBITDA ratio of 1.50 to 1.00, or if greater than 1.50 to 1.00, a Fixed Charge Coverage Ratio of 1.10 to 1.00, in conjunction with maintaining unused availability thresholds of borrowing capacity, as defined in the ~~NACoal~~ Facility, of $15.0 million. At ~~September~~June 30, ~~2022, NACoal~~2023, NACCO Natural Resources was in compliance with all financial covenants in the ~~NACoal~~ Facility.

The obligations under the ~~NACoal~~ Facility are guaranteed by certain of ~~NACoal's~~NACCO Natural Resource's direct and indirect, existing and future

domestic subsidiaries, and is secured by certain assets of ~~NACoal~~NACCO Natural Resources and the guarantors, subject to customary exceptions and

limitations.

The Company believes funds available from cash on hand, the ~~NACoal~~ Facility and operating cash flows will provide sufficient liquidity to meet its operating needs and commitments arising during the next twelve months and until the expiration of the ~~NACoal~~ Facility in November 2025.

Expenditures for property, plant and equipment and mineral interests

Expenditures for property, plant and equipment and mineral interests were ~~$42.0~~$14.1 million during the first ~~nine~~six months of ~~2022.~~2023. Planned expenditures for the remainder of ~~2022~~2023 are expected to be approximately ~~$14~~$26 million in the NAMining segment, $20 million in the Minerals Management segment, $7 million in the Coal Mining segment $3and less than $1.0 million in the NAMining segment and $2 million at Mitigation Resources. Planned expenditures for 2023 are expected to be approximately $10 million in the Coal Mining segment, $29 million in the NAMining segment and $10 million in the Minerals Management segment.Unallocated Items.

In the ~~Coal Mining~~NAMining segment, ~~elevated levels of expected~~2023 capital expenditures ~~through 2022~~ are primarily related to spending at MLMC as it develops a new mine area. In the NAMining segment, expected capital expenditures through 2023 are primarily for the acquisition, relocation and refurbishment of draglines as well as the acquisition of other mining equipment to support the expansion of contract mining services beyond NAMining's historical dragline-oriented model, including the acquisition of equipment to ~~support~~be used at the

Thacker Pass lithium project. Sawtooth is the contract miner for the Thacker Pass lithium project. Under the terms of the contract mining agreement, the customer will reimburse Sawtooth for these capital expenditures over a five-year period from the equipment acquisition date.

Expenditures are expected to be funded from internally generated funds and/or bank borrowings.

Capital Structure

NACCO's consolidated capital structure is presented below:


		SEPTEMBER 30 2022		DECEMBER 31 2021		Change			JUNE 30 2023		DECEMBER 31 2022		Change
Cash and cash equivalents	Cash and cash equivalents	$	92,754	$	86,005	$	6,749	Cash and cash equivalents	$	117,016	$	110,748	$	6,268
Other net tangible assets	Other net tangible assets	333,506		276,733		56,773		Other net tangible assets	334,811		329,045		5,766
Intangible assets, net	Intangible assets, net	29,001		31,774		(2,773)		Intangible assets, net	26,401		28,055		(1,654)
Net assets	Net assets	455,261		394,512		60,749		Net assets	478,228		467,848		10,380
Total debt	Total debt	(18,277)		(20,710)		2,433		Total debt	(23,729)		(19,668)		(4,061)
Bellaire closed mine obligations	Bellaire closed mine obligations	(21,563)		(21,686)		123		Bellaire closed mine obligations	(21,101)		(21,214)		113
Total equity	Total equity	$	415,421	$	352,116	$	63,305	Total equity	$	433,398	$	426,966	$	6,432
Debt to total capitalization	Debt to total capitalization	4%		6%		(2)%		Debt to total capitalization	5%		4%		1%

The increase in other net tangible assets at ~~September~~June 30, ~~2022~~2023 compared with December 31, ~~2021~~2022 was ~~primarily~~mainly the result of an

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increase in Trade accounts receivable due to ~~an increase~~higher sales at NAMining and Mitigation Resources as well as a decrease in ~~Property, plant and equipment,~~Accrued payroll for payments made under the ~~receipt~~Company's incentive compensation plans during the first six months of ~~the membership units~~2023. These items were partially offset by a reduction in ~~a privately-held company and office building that were transferred from GRE with a fair value of $12.8 million and $4.1 million, respectively, and an increase in~~the Federal income tax ~~receivable.~~receivable during the first six months of 2023.

Contractual Obligations, Contingent Liabilities and Commitments

Since December 31, ~~2021,~~2022, there have been no significant changes in the total amount of NACCO's contractual obligations, contingent liabilities or commercial commitments, or the timing of cash flows in accordance with those obligations as reported on ~~pages 50 through 51~~page 58 in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2021.~~2022. See Note 6 to the Unaudited Condensed Consolidated Financial Statements for a discussion of certain guarantees related to Coyote Creek.

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SEGMENT RESULTS

COAL MINING SEGMENT

FINANCIAL REVIEW

Tons of coal delivered by the Coal Mining segment were as follows for the three and ~~nine~~six months ended ~~September~~June 30:


		THREE MONTHS		NINE MONTHS			THREE MONTHS		SIX MONTHS
		2022	2021	2022	2021		2023	2022	2023	2022
Unconsolidated operations	Unconsolidated operations	7,210	8,206	19,061	21,733	Unconsolidated operations	4,602	5,534	10,794	11,851
Consolidated operations	Consolidated operations	750	768	2,397	2,378	Consolidated operations	906	915	1,617	1,647
Total tons delivered	Total tons delivered	7,960	8,974	21,458	24,111	Total tons delivered	5,508	6,449	12,411	13,498

The results of operations for the Coal Mining segment were as follows for the three and ~~nine~~six months ended ~~September~~June 30:

THREE MONTHS NINE MONTHS
2022 2021 2022 2021
Revenues $ 22,599 $ 20,946 $ 70,163 $ 63,577
Cost of sales 20,933 17,817 64,421 55,950
Gross profit 1,666 3,129 5,742 7,627
Earnings of unconsolidated operations(a)
13,300 16,380 40,086 42,718
Contract termination settlement — 10,333 14,000 10,333
Selling, general and administrative expenses 8,008 6,960 22,439 20,152
Amortization of intangible assets 867 902 2,772 2,795
Loss (gain) on sale of assets 2 (5) 1 (38)
Operating profit $ 6,089 $ 21,985 $ 34,616 $ 37,769


	THREE MONTHS				SIX MONTHS
	2023		2022		2023		2022
Revenues	$	26,343	$	26,602	$	46,996	$	47,564
Cost of sales	33,269		24,638		59,147		43,488
Gross (loss) profit	(6,926)		1,964		(12,151)		4,076
Earnings of unconsolidated operations(a)	9,962		13,460		22,428		26,786
Contract termination settlement	—		14,000		—		14,000
Selling, general and administrative expenses	6,716		7,192		13,153		14,431
Amortization of intangible assets	927		1,058		1,654		1,905
Loss (gain) on sale of assets	68		(1)		(168)		(1)
Operating (loss) profit	$	(4,675)	$	21,175	$	(4,362)	$	28,527

(a) See Note 6 to the Unaudited Condensed Consolidated Financial Statements for a discussion of the Company's unconsolidated subsidiaries, including summarized financial information.

~~Third~~

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Second Quarter of ~~2022~~2023 Compared with ~~Third~~Second Quarter of ~~2021~~2022

Revenues ~~increased 7.9%~~ in the ~~third~~second quarter of ~~2022 compared with~~2023 were comparable to the ~~third~~second quarter of ~~2021 primarily due to a higher per ton sales price at MLMC.~~2022.

The following table identifies the components of change in operating (loss) profit for the ~~third~~second quarter of ~~2022~~2023 compared with the ~~third~~second quarter of ~~2021:~~2022:


		Operating Profit			Operating (Loss) Profit
2021		$	21,985
2022				2022	$	21,175
Increase (decrease) from:	Increase (decrease) from:			Increase (decrease) from:
Contract termination settlement received in 2021		(10,333)
Contract termination settlement				Contract termination settlement	(14,000)
Gross profit, excluding inventory impairment charge				Gross profit, excluding inventory impairment charge	(7,094)
Earnings of unconsolidated operations	Earnings of unconsolidated operations	(3,080)		Earnings of unconsolidated operations	(3,498)
Gross profit		(1,463)
Inventory impairment charge				Inventory impairment charge	(1,796)
Loss on sale of assets				Loss on sale of assets	(69)
Selling, general and administrative expenses	Selling, general and administrative expenses	(1,048)		Selling, general and administrative expenses	476
Gain on sale of assets		(7)
Amortization of intangibles	Amortization of intangibles	35		Amortization of intangibles	131
2022		$	6,089
2023				2023	$	(4,675)

Operating (loss) profit decreased ~~$15.9~~$25.9 million in the ~~third~~second quarter of 2023 compared with the second quarter of 2022. This decrease was primarily due to the non-recurrence of $14.0 million recognized in the second quarter of 2022 ~~compared with the third quarter of 2021 due to the $10.3 million payment~~ related to the ~~Bisti~~ contract termination ~~recognized during the third quarter of 2021,~~settlement with GRE, a decrease in gross profit and a decrease in the earnings of unconsolidated operations, ~~a decrease in gross profit and an increase in~~partially offset by lower selling, general and administrative ~~expenses.~~

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The decrease in earnings of unconsolidated operations was primarily due to a reduction in the per ton management fee at Falkirk as well as the Bisti contract termination as of September 30, 2021. These decreases were partially offset by an increase in customer requirements at Coteau.

~~The decrease in gross profit was primarily due to an increase in the cost per ton delivered at MLMC, due in part to an increase in the costs of diesel fuel as well as repairs and maintenance expense.~~

~~The increase in selling, general and administrative expenses was primarily due to higher employee-related costs.~~

~~First Nine Months of 2022 Compared with First Nine Months of 2021~~

~~Revenues increased 10.4% in the first nine months of 2022 compared with the first nine months of 2021 primarily due to a higher per ton sales price at MLMC.~~

~~The following table identifies the components of change in operating profit for the first nine months of 2022 compared with the first nine months of 2021:~~

Operating Profit
2021 $ 37,769
Increase (decrease) from:
Earnings of unconsolidated operations (2,632)
Selling, general and administrative expenses (2,287)
Gross profit (1,885)
Gain on sale of assets (39)
Contract termination settlements in 2022 and 2021, net 3,667
Amortization of intangibles 23
2022 $ 34,616

Operating profit decreased $3.2 million in the first nine months of 2022 compared with the first nine months of 2021 primarily due to a decrease in the earnings of unconsolidated operations, an increase in selling, general and administrative expenses and a decrease in gross profit.

The decrease in earnings of unconsolidated operations was primarily due to a reduction in earnings as a result of the Bisti contract termination as of September 30, 2021 as well as a reduction in the per ton management fee at Falkirk. These decreases were partially offset by a contractual price escalation and an increase in customer requirements at Coteau.

~~The increase in selling, general and administrative expenses was primarily due to higher employee-related costs and professional service~~ expenses.

The decrease in gross profit was primarily due to an increase in the cost per ton delivered at MLMC. The increase in cost per ton delivered at MLMC is due to costs associated with establishing operations in ~~part~~a new mine area and a reduction in the number of tons severed. The reduction in severed tons was due to adverse mining conditions caused by the amount of rain during the second quarter of 2023, as well as operational inefficiencies related to final mining activities at the existing mine area. Fewer tons severed caused a decrease in tons held in inventory since more tons were delivered than produced during the second quarter of 2023, which resulted in an increase in the cost per ton and a $1.8 million inventory impairment charge to write down coal inventory to its net realizable value.

The decrease in the earnings of unconsolidated operations was primarily due to:

•A reduction in earnings at Coteau due to reduced customer requirements and a change in price;

•A reduction in the per ton management fee at Falkirk effective May 2022 through May 2024 to support the transition of the Coal Creek Station Power Plant to Rainbow Energy, as well as a reduction in customer requirements; and

•A reduction in earnings at Sabine, which ceased deliveries in the first quarter of 2023 and began final reclamation on April 1, 2023.

These decreases in the earnings of unconsolidated operations were partly offset by improved results at Coyote Creek.

The decrease in selling, general and administrative expenses was primarily due to lower employee-related costs.

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First Six Months of 2023 Compared with First Six Months of 2022

Revenues in the first six months of 2023 were comparable to the first six months of 2022.

The following table identifies the components of change in operating (loss) profit for the first six months of 2023 compared with the first six months of 2022:


	Operating (Loss) Profit
2022	$	28,527
Increase (decrease) from:
Contract termination settlement	(14,000)
Gross profit, excluding inventory impairment charges	(12,007)
Earnings of unconsolidated operations	(4,358)
Inventory impairment charges	(4,220)
Selling, general and administrative expenses	1,278
Amortization of intangibles	251
Gain on sale of assets	167
2023	$	(4,362)

Operating (loss) profit decreased $32.9 million in the first six months of 2023 compared with the first six months of 2022 due to the non-recurrence of $14.0 million recognized in the second quarter of 2022 related to the contract termination settlement with GRE, a decrease in gross profit and a decline in the earnings of unconsolidated operations, partially offset by lower selling, general and administrative expenses.

The decrease in gross profit was primarily due to an increase in the cost per ton delivered at MLMC. The increase in cost per ton delivered at MLMC is due to costs associated with establishing operations in a new mine area and a reduction in the number of ~~diesel fuel.~~tons severed. The reduction in severed tons was due to adverse mining conditions caused by the amount of rain during the first six months of 2023, as well as operational inefficiencies related to final mining activities at the existing mine area. Fewer tons severed caused a decrease in tons held in inventory since more tons were delivered than produced during the first six months of 2023, which resulted in an increase in the cost per ton and $4.2 million of inventory impairment charges to write down coal inventory to its net realizable value.

The decrease in the earnings of unconsolidated operations was primarily due to a reduction in the per ton management fee at Falkirk effective May 2022 through May 2024 to support the transition of the Coal Creek Station Power Plant to Rainbow Energy as well as a reduction in customer requirements. A reduction in earnings at Coteau due to reduced customer requirements also contributed to the decrease in the earnings of unconsolidated operations. These decreases ~~in operating profit~~ were ~~partially~~partly offset by ~~an increase~~improved results at Coyote Creek.

The decrease in ~~contract termination settlements. The $14.0 million contract termination settlement from GRE recognized during the second quarter of 2022~~selling, general and administrative expenses was ~~partially offset by the $10.3 million payment related~~primarily due to ~~the Bisti contract termination recognized during the third quarter of 2021.~~lower employee-related costs.

NORTH AMERICAN MINING ("NAMining") SEGMENT

FINANCIAL REVIEW

Tons delivered by the NAMining segment were as follows for the three and ~~nine~~six months ended ~~September~~June 30:

THREE MONTHS NINE MONTHS
2022 2021 2022 2021
Total tons delivered 13,421 14,215 40,756 40,460


	THREE MONTHS		SIX MONTHS
	2023	2022	2023	2022


Total tons delivered	13,939	13,373	28,768	27,335

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The results of operations for the NAMining segment were as follows for the three and ~~nine~~six months ended ~~September~~June 30:

THREE MONTHS NINE MONTHS
2022 2021 2022 2021
Total revenues $ 22,962 $ 20,429 $ 67,180 $ 58,228
Reimbursable costs 15,259 12,278 41,337 37,835
Revenues excluding reimbursable costs $ 7,703 $ 8,151 $ 25,843 $ 20,393
Total revenues $ 22,962 $ 20,429 $ 67,180 $ 58,228
Cost of sales 21,853 18,886 62,086 53,678
Gross profit 1,109 1,543 5,094 4,550
Earnings of unconsolidated operations(a)
1,288 1,272 3,716 3,818
Selling, general and administrative expenses 2,607 1,372 6,417 4,510
Loss (gain) on sale of assets — (5) 75 55
Operating profit (loss) $ (210) $ 1,448 $ 2,318 $ 3,803


	THREE MONTHS				SIX MONTHS
	2023		2022		2023		2022
Total revenues	$	21,716	$	22,814	$	42,349	$	44,218
Reimbursable costs	12,656		14,062		24,749		26,078
Revenues excluding reimbursable costs	$	9,060	$	8,752	$	17,600	$	18,140

Total revenues	$	21,716	$	22,814	$	42,349	$	44,218
Cost of sales	18,884		20,583		38,125		40,233
Gross profit	2,832		2,231		4,224		3,985
Earnings of unconsolidated operations(a)	1,122		1,162		2,480		2,428
Selling, general and administrative expenses	1,740		2,056		3,660		3,810
Loss on sale of assets	—		80		—		75
Operating profit	$	2,214	$	1,257	$	3,044	$	2,528

(a) See Note 6 to the Unaudited Condensed Consolidated Financial Statements for a discussion of the Company's unconsolidated subsidiaries, including summarized financial information.

~~Third~~Second Quarter of ~~2022~~2023 Compared with ~~Third~~Second Quarter of ~~2021~~2022

Total revenues ~~increased 12.4%~~decreased 4.8% in the ~~third~~second quarter of 2023 compared with the second quarter of 2022 ~~compared with the third quarter of 2021~~ primarily due to an increase in reimbursable costs, which have an offsetting amount in cost of sales and have no impact on operating profit, as well as a higher average per ton sales price at the consolidated operations. These improvements were partially offset by a reduction in revenue from reclamation activities at Caddo Creek as ~~the scope of final reclamation activities declined.~~

~~The following table identifies the components of change in operating profit (loss) for the third quarter of 2022 compared with the third quarter of 2021:~~

Operating Profit (Loss)
2021 $ 1,448
Increase (decrease) from:
Selling, general and administrative expenses (1,000)
Voluntary retirement program charge (769)
Gain on sale of assets (5)
Gross profit 100
Earnings of unconsolidated operations 16
2022 $ (210)

Operating profit decreased $1.7 million in the third quarter of 2022 compared with the third quarter of 2021 primarily due to an increase in selling, general and administrative expenses and a voluntary retirement charge.

~~During the third quarter of 2022, the Company implemented a voluntary retirement program for employees who met certain age and service requirements to reduce overall headcount. As~~ a result of ~~this program,~~ the ~~third quarter 2022 operating loss includes a charge~~Company's first-quarter 2023 acquisition of ~~$0.8 million related to one-time termination benefits. The increase in selling, general and administrative expenses~~Marshall Mine, where Caddo Creek had been performing mine reclamation work. This decrease was ~~mainly due to higher employee-related costs.~~

~~The increase in gross profit was due to higher earnings at consolidated quarries,~~ partially offset by ~~a reduction in earnings~~revenue from mining operations at ~~Caddo Creek as~~an additional quarry added during the ~~scope~~fourth quarter of ~~final mine reclamation activities declined.~~

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~~First Nine Months of 2022 Compared with First Nine Months of 2021~~

Total revenues increased 15.4% in the first nine months of 2022 compared with the first nine months of 2021 primarily due to an increase in reimbursable costs, which have an offsetting amount in cost of sales and have no impact on operating profit, as well as an increase in customer requirements and tons delivered at the consolidated operations.2022.

The following table identifies the components of change in operating profit for the ~~first nine months~~second quarter of ~~2022~~2023 compared with the ~~first nine months~~second quarter of ~~2021:~~2022:


		Operating Profit			Operating Profit
2021		$	3,803
2022				2022	$	1,257
Increase (decrease) from:	Increase (decrease) from:			Increase (decrease) from:
Gross profit				Gross profit	601
Selling, general and administrative expenses	Selling, general and administrative expenses	(1,672)		Selling, general and administrative expenses	316
Voluntary retirement program charge		(769)
Loss on sale of assets				Loss on sale of assets	80
Earnings of unconsolidated operations	Earnings of unconsolidated operations	(102)		Earnings of unconsolidated operations	(40)
Loss on sale of assets		(20)
Gross profit		1,078
2022		$	2,318
2023				2023	$	2,214

Operating profit ~~decreased $1.5~~increased $1.0 million in the ~~first nine months~~second quarter of ~~2022~~2023 compared with the ~~first nine months~~second quarter of ~~2021~~2022 primarily due to an increase in gross profit and a decrease in selling, general and administrative ~~expenses and a voluntary retirement charge,~~expenses. The increase in gross profit was due to higher earnings at the consolidated quarries as well as an increase in dragline part sales, partially offset by ~~an increase in gross profit.~~

~~During~~ the ~~third quarter~~absence of 2022, the Company implemented a voluntary retirement program for employees who met certain age and service requirements to reduce overall headcount. As a result of this program, the third quarter 2022 operating loss includes a charge of $0.8 million related to one-time termination benefits.earnings associated with Caddo Creek reclamation activities. The ~~increase~~decrease in selling, general and administrative expenses was ~~primarily~~mainly due to ~~higher~~lower employee-related costs.

First Six Months of 2023 Compared with First Six Months of 2022

Total revenues decreased 4.2% in the first six months of 2023 compared with the first six months of 2022 primarily due to a reduction in revenue from reclamation activities at Caddo Creek as a result of the Company's first-quarter 2023 acquisition of Marshall Mine, where Caddo Creek had been performing mine reclamation work.

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The following table identifies the components of change in operating profit for the first six months of 2023 compared with the first six months of 2022:


	Operating Profit
2022	$	2,528
Increase (decrease) from:
Gross profit	239
Selling, general and administrative expenses	150
Loss on sale of assets	75
Earnings of unconsolidated operations	52
2023	$	3,044

Operating profit increased $0.5 million in the first six months of 2023 compared with the first six months of 2022 primarily due to an increase in gross profit and a decrease in selling, general and administrative expenses. The increase in gross profit was ~~primarily attributable~~due to higher earnings at the consolidated quarries as well as an increase in dragline part sales, partially offset by the absence of earnings associated with ~~the reclamation contract and water sales at~~ Caddo Creek ~~partially offset by a~~reclamation activities. The decrease in ~~gross profit from the active operations~~selling, general and administrative expenses was mainly due to ~~an increase in~~lower employee-related costs.

MINERALS MANAGEMENT SEGMENT

FINANCIAL REVIEW

The results of operations for the Minerals Management segment were as follows for the three and ~~nine~~six months ended ~~September~~June 30:


		THREE MONTHS				NINE MONTHS					THREE MONTHS				SIX MONTHS
		2022		2021		2022		2021			2023		2022		2023		2022
Revenues	Revenues	$	16,172	$	10,607	$	40,888	$	21,715	Revenues	$	9,171	$	11,962	$	17,456	$	24,716
Cost of sales	Cost of sales	1,006		755		2,487		2,398		Cost of sales	910		733		1,962		1,481
Gross profit	Gross profit	15,166		9,852		38,401		19,317		Gross profit	8,261		11,229		15,494		23,235
Selling, general and administrative expenses	Selling, general and administrative expenses	611		398		1,672		1,455		Selling, general and administrative expenses	972		552		2,161		1,061
Gain on sale of assets	Gain on sale of assets	—		—		(2,527)		—		Gain on sale of assets	—		(2,396)		—		(2,527)
Asset impairment charges		3,939		—		3,939		—

Operating profit	Operating profit	$	10,616	$	9,454	$	35,317	$	17,862	Operating profit	$	7,289	$	13,073	$	13,333	$	24,701

During the ~~three~~second quarter of 2023 and ~~nine~~the first six months ~~ended September 30, 2022,~~of 2023, the oil and natural gas industry experienced ~~continued improvement~~a decline in commodity prices compared with the respective ~~2021 periods, primarily due to:~~

•~~Higher demand as the impact from COVID-19 abates;~~

•~~Changes in domestic supply and demand dynamics as well as increased discipline around production and capital investments by oil and gas companies; and~~

•~~Instability and constraints on global supply, particularly with respect to instability in Russia and Ukraine.~~

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2022 periods. Oil and natural gas prices have been historically volatile and may continue to be volatile in the future. The table below demonstrates such volatility with the average price as reported by the United States Energy Information Administration for the three and ~~nine~~six months ended ~~September~~June 30:

THREE MONTHS NINE MONTHS
2022 2021 2022 2021
West Texas Intermediate Average Crude Oil Price $ 93.18 $ 70.62 $ 98.79 $ 64.83
Henry Hub Average Natural Gas Price $ 7.99 $ 4.36 $ 6.71 $ 3.62


	THREE MONTHS				SIX MONTHS
	2023		2022		2023		2022
West Texas Intermediate Average Crude Oil Price	$	73.76	$	108.72	$	74.92	$	101.59
Henry Hub Average Natural Gas Price	$	2.16	$	7.48	$	2.41	$	6.07

Revenues and operating profit ~~increased~~decreased significantly in the ~~three~~second quarter of 2023 and ~~nine~~the first six months ~~ended September 30, 2022~~of 2023 compared with the respective ~~2021 periods. The increase is~~2022 periods, primarily due to substantially ~~higher~~lower natural gas and oil prices ~~increased production due in part to income generated from newly developed wells on Company leases during~~and the recognition of less settlement income. The second quarter of 2023 and the first quarter of 2022 ~~as well as~~included $1.4 million and $2.1 million of settlement income, ~~recognized during the first quarter of 2022. The settlement~~respectively. Settlement income relates to the Company’s ownership interest in certain mineral rights.

In addition, operating profit ~~increased~~in the second quarter of 2023 decreased due to a $2.4 million gain on the sale of land related to legacy operations during the second quarter of 2022.

~~The Company regularly performs reviews of potential future development projects~~An increase in selling, general and ~~identified certain legacy coal assets where future development is unlikely. The long-lived assets, which included land, prepaid royalties and capitalized leasehold~~administrative expenses, mainly due to higher employee-related costs, ~~were written off~~also contributed to the decrease in ~~the third quarter of 2022 and resulted in non-cash asset impairment charges of $3.9 million.~~operating profit.

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UNALLOCATED ITEMS AND ELIMINATIONS

FINANCIAL REVIEW

Unallocated Items and Eliminations were as follows for the three and ~~nine~~six months ended ~~September~~June 30:

THREE MONTHS NINE MONTHS
2022 2021 2022 2021
Operating loss $ (6,677) $ (5,295) $ (17,806) $ (14,842)


	THREE MONTHS				SIX MONTHS
	2023		2022		2023		2022
Operating loss	$	(3,078)	$	(5,822)	$	(8,451)	$	(11,129)

The operating loss ~~increased $1.4 million and $3.0 million~~ in the ~~three~~second quarter of 2023 and ~~nine~~the first six months ~~ended September 30, 2022, respectively,~~of 2023 decreased compared with the respective ~~2021~~2022 periods ~~primarily~~ due to higher earnings at Mitigation Resources and lower employee-related costs.

NACCO Industries, Inc. Outlook

Coal Mining Outlook ~~- 2022~~

~~In fourth-quarter 2022, the Company expects coal~~

Coal deliveries ~~to increase moderately from 2021, while the Coal Mining segment operating profit is~~for second-half and full-year 2023 are expected to ~~be comparable to~~decrease from 2022 levels. The owner of the ~~prior year. Lower earnings anticipated at~~power plant served by the ~~Falkirk~~Company's Sabine Mine in Texas retired the Pirkey power plant, and as a result ofSabine ceased deliveries March 31, 2023. This is the ~~reduction~~primary driver for the year-over-year declines in the per ton management fee through May 2024, to support the transition of the Coal Creek Station Power Plant to Rainbow Energy, are expected to be offset by higher earnings at Coteau due to an increase in tons delivered and contractual price escalation. Segment Adjusted EBITDA is expected to increase modestly primarily due to improved EBITDA at MLMC where increased depreciation expense associated with capital expenditures in recent years has negatively affected operating profit.coal deliveries.

Coal Mining operating profit and Segment Adjusted EBITDA ~~for the 2022 full year is~~are also expected to decrease significantly in both the 2023 second half and full year compared with ~~2021, both~~the respective 2022 periods, including and excluding the contract termination ~~payments~~payment received in ~~2022 and 2021.~~2022. The expected ~~reductions are~~reduction in operating profit for the remainder of 2023 is primarily the result of reduced earnings at both the consolidated and unconsolidated ~~coal~~Coal Mining operations.

Results at the consolidated mining operations ~~as well as higher operating expenses recognized~~are projected to decrease significantly in the second half of 2023 from the comparable 2022 period. This expected decrease is mainly due to an expected substantial decline in earnings at MLMC from decreased customer demand and increased costs associated with establishing operations in a new mine area. The year-over-year decrease in second-half 2023 results is expected to be lower than the decrease experienced in the first ~~nine months~~half of ~~2022.~~

~~Capital~~2023 because the anticipated inefficiencies of this project are expected to continue through the third quarter and then moderate beginning in the fourth quarter of 2023 and into 2024. MLMC does not anticipate opening additional mine areas through the remaining contract term. As a result, mine development capital expenditures are expected to moderate from 2024 through 2032. While increased depreciation from capital expenditures related to the new mine area will affect future results, the Company anticipates MLMC should contribute favorably to Segment Adjusted EBITDA in future years. In 2023, capital expenditures are expected to be ~~approximately $14~~$11 million, with $7 million expended in the ~~fourth quarter~~second half of 2023, primarily for mine development and equipment replacement.

The anticipated reduction in earnings at the unconsolidated Coal Mining operations for the second half of 2023 from second half of 2022 is primarily due to the early retirement of the Pirkey power plant and ~~approximately $25 million~~commencement of final reclamation at the Sabine Mine, which began April 1, 2023. Sabine is receiving compensation for providing final mine reclamation services, but at a lower rate than during active mining. Funding for Sabine's mine reclamation is the ~~2022 full year.~~responsibility of the customer. A decrease in earnings at Falkirk and Coteau is also expected to contribute to the lower earnings of unconsolidated operations.

The Company's contract structure at each of its coal mining operations eliminates exposure to spot coal market price fluctuations. However, fluctuations in natural gas prices, weather and the availability of renewable power generation, particularly wind, can contribute to changes in power plant dispatch and customer demand for coal. ~~Sustained higher natural gas prices could result in increased demand for coal.~~ Changes to ~~expectations for~~ customer power plant dispatch ~~could~~would affect the Company’s outlook for the remainder of ~~2022 and~~ 2023, as well as over the longer term. ~~The owner of the power plant served by the Company's Sabine Mine in Texas intends to retire the power plant in 2023. Sabine expects deliveries to cease in the first quarter~~

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~~of 2023 at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the responsibility of the customer.~~

~~Coal Mining Outlook - 2023~~

In 2023, the Company expects coal deliveries to decrease moderately from 2022 levels as a result of the cessation of Sabine deliveries in the 2023 first quarter and current expectations of customer requirements.

Coal Mining operating profit and Segment Adjusted EBITDA for the 2023 full year are expected to decrease significantly compared with 2022, including and excluding the $14.0 million GRE termination payment received in 2022. The decline is primarily the result of an expected significant reduction in earnings at the consolidated operations and an anticipated modest decrease in earnings of unconsolidated operations.

Results at the consolidated mining operations are projected to decrease significantly predominantly due to an expected substantial decline in earnings at MLMC driven by an increase in the cost per ton of coal delivered in 2023 versus 2022. Anticipated cost inflation on repairs, diesel fuel and supplies, as well as higher depreciation expense related to recent capital expenditures to develop a new mine area are expected to contribute to the higher cost per ton. MLMC sells lignite at contractually agreed upon prices which are subject to changes in the level of established indices generally reflecting inflation over time. The increase in production costs will not be offset by an immediate increase in the revenue generated from contractual price escalation as there is a lag in the timing of the effect of inflation on the index-based coal sales price.

The anticipated lower earnings at the unconsolidated coal mining operations is expected to be driven primarily by the reduction in the per ton management fee at Falkirk for all 12 months in 2023 compared with 7 months in 2022, as well as the cessation of Sabine deliveries starting late in the first quarter of 2023. These decreases are expected to be partly offset by higher earnings at Coteau.

~~Capital expenditures are expected to be approximately $10 million in 2023.~~

NAMining Outlook

NAMining expects ~~tons delivered,~~ operating profit and Segment Adjusted EBITDA to increase in both the 2023 second half and full year over the respective 2022 ~~fourth quarter~~periods but decrease from the 2023 first half. The second-half increase over 2022 is primarily because the second half of ~~anticipated increased earnings under existing contracts, including Sawtooth Mining. Excluding the effect of the~~2022 included a $0.8 million charge ~~for the~~related to a voluntary retirement ~~program, full-year operating profit~~program. A reduction in Caddo Creek earnings is expected to ~~increase over 2021.~~

~~Segment Adjusted EBITDA for the 2022 full year is expected to increase significantly compared with the prior year, including and excluding the third quarter voluntary retirement charge.~~be offset by improvements at other NAMining operations. This anticipated improvement is ~~a result of the~~due in part to profit improvement ~~in operating profit~~initiatives underway, as well as contributions from ~~higher reclamation income at Caddo Creek in the first nine months of 2022 and increased results at the active~~ mining operations ~~and Sawtooth Mining partially offset by~~commencing at an ~~increase in operating expenses.~~additional quarry during the fourth quarter of 2022.

In 2023, NAMining expects full-year operating profit and Segment Adjusted EBITDA to increase significantly over 2022 due to increased results from active mining operations and an anticipated reduction in operating expenses, in part due to an anticipated reduction in employee-related costs from the voluntary retirement program.

~~NAMining continues to have a substantial pipeline of potential new projects and is pursuing a number of growth initiatives that, if successful, would be accretive to future earnings.~~

In 2019, Sawtooth Mining, LLC, entered into a mining services agreement to serve as the exclusive contract miner for the Thacker Pass lithium project in northern Nevada, owned by Lithium Nevada Corp., a subsidiary of Lithium Americas Corp. (TSX: LAC) (NYSE: LAC). Lithium Americas owns the lithium reserves at Thacker Pass and will be responsible for the processing and sale of the lithium produced. In October 2022, Lithium Americas provided an update on the Thacker Pass project, which noted that all key state-level permits had been issued for Thacker Pass, feasibility study results are expected in the first quarter of 2023 and construction is expected to begin in 2023. At maturity, this management fee contract is expected to deliver fee income similar to a mid-sized management fee coal mine.

NAMining expects full-year 2022 capital expenditures to be approximately $12 million, with approximately $3 million expended in the fourth quarter primarily for the acquisition, relocation and refurbishment of draglines, as well as the acquisition of other mining equipment to support the continued expansion of contract-mining services. In 2023, capital expenditures are expected to be ~~approximately $29~~$35 million, with $26 million expended in the second half of 2023, primarily for the acquisition of equipment to support the Thacker Pass lithium project. ~~The cost of mining equipment related to Thacker Pass will be reimbursed by the customer over a five-year period from the equipment acquisition date.~~

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Minerals Management Outlook

The Minerals Management segment derives income from royalty-based leases under which lessees make payments to the Company based on their sale of natural gas, oil, natural gas liquids and coal, extracted primarily by third parties. Changing prices of natural gas and oil could have a significant impact on Minerals Management’s operating profit.

~~In the 2022 fourth quarter and full year, operating~~Operating profit and Segment Adjusted EBITDA ~~are expected to continue to increase significantly over~~for the ~~respective prior~~2023 second half and full year ~~periods primarily driven by current expectations for natural gas and oil prices and increases in production volumes.~~

~~In 2023, operating profit and Segment Adjusted EBITDA~~ are expected to decrease significantly compared with the respective 2022 periods. These decreases are primarily driven by current market expectations for natural gas and oil ~~prices, an anticipated reduction~~prices. Based on current market expectations, operating profit in ~~volumes as existing wells follow their natural production~~the second half is expected to decline ~~and limited forecasted development~~moderately from the first half of ~~additional new wells by third-party lessees.~~2023.

~~Based on market expectations, the~~The Company's forecast ~~assumes~~is based on current market assumptions for natural gas and oil ~~and gas~~ market ~~prices moderate in 2023 to levels in line with 2021 averages;~~prices; however, commodity prices are inherently volatile. ~~The actions of OPEC, the Russia-Ukraine conflict, inventory levels of natural gas~~Growing economic uncertainty continues to drive commodity price volatility and ~~oil and the uncertainty associated with demand, as well as other factors, have the potential to impact future oil and gas prices. An increase~~any change in natural gas and oil prices ~~above~~from current expectations ~~could~~will result in ~~improvements~~adjustments to the ~~2023 forecast.~~Company's outlook.

As an owner of royalty and mineral interests, the Company’s access to information concerning activity and operations with respect to its interests is limited. The Company's expectations are based on the best information currently available and could vary positively or negatively as a result of adjustments made by operators, additional leasing and development and/or changes to commodity prices. ~~The production decline is particularly pronounced in new wells, such as those that began production in the fourth quarter of 2021 and early in 2022 on Company leases.~~ Development of ~~new~~additional wells on existing interests in excess of current expectations could be accretive to future results.

In ~~the third quarter of 2022,~~2023, Minerals Management ~~completed an $11.4~~expects capital expenditures of approximately $21 million, ~~acquisition~~which includes up to $20 million of ~~mineral interests in the Texas portion of the Permian Basin and the Wyoming portion of the Powder River Basin. Minerals Management is targeting~~ additional investments induring the second half of 2023 that align with the Company's strategy and objectives to establish a diversified portfolio of mineral and royalty ~~interests of up~~interests. Future investments are expected to ~~$10 million in 2023. Potential future acquisitions could~~ be accretive, but each investment's contribution to ~~2023 results~~near-term earnings is dependent on the details of that investment, including the size and type of interests acquired and the stage and timing of mineral development.

Consolidated Outlook

~~Consolidated Outlook~~

~~NACCO~~Overall, the Company expects ~~a significant increase~~consolidated results to continue to decrease in ~~consolidated operating profit, net income and Consolidated Adjusted EBITDA~~the third quarter before improving in the fourth quarter. The improvement in fourth quarter 2023 results will not offset the anticipated third quarter decline. Therefore, earnings in the second half of 2023 are expected to be lower than both the first half of 2023 and the second half of 2022, ~~due to anticipated higher results~~primarily driven by activity at the Minerals Management and ~~NAMining segments, as well as income from an equity interest in a North Dakota-based ethanol business.~~

~~For~~Coal Mining segments. At Minerals Management, the 2022 full year, excluding the settlements associated with the GRE/Rainbow Energy transaction recognized in 2022 and the Bisti termination fee recognized in 2021, NACCO expects consolidated operating profit, net income and Consolidated Adjusted EBITDA to improve significantly over 2021. Substantially higher earningsdecrease in the ~~Minerals Management segment, as well as income~~second half of 2023 is primarily driven by the expected continued reduction in commodity prices from ~~an equity interest in a North Dakota-based ethanol business, are expected to be partially offset by significantly lower operating profit from~~2022 price levels. At the Coal Mining segment, ~~and an increase in unallocated employee-related expenses. In addition, income recognized in 2021 on exchange-traded equity securities held by the Company is not expected to reoccur due to~~ a ~~deterioration in public equity markets during 2022. The effective income tax rate, including the settlements associated with the GRE/Rainbow Energy transaction,~~higher cost per ton at MLMC is expected to ~~be between 15% and 17%.~~

reduce earnings in the second half of 2023, particularly the third quarter. In ~~2023, NACCO expects consolidated net income to decrease significantly~~addition, a reduction in earnings from ~~2022 largely due to $30.9 million of pre-tax contract termination income recognized during 2022. Excluding~~ the ~~effect of the contract termination settlements, net income~~unconsolidated mines is expected to ~~decrease substantially due~~contribute to ~~significantly reduced royalty income at~~ the ~~Minerals Management segment and lower earnings in the Coal Mining segment, as well as an anticipated reduction in income from an equity interest in a North Dakota-based ethanol business.~~decrease. These reductions are expected to be partially offset by lower income tax ~~expense and improved results in the NAMining segment.~~expense. The Company expects ana negative effective income tax rate between 2%5% and 5%10% for the 2023 full year.

Management continues to view the long-term business outlook for NACCO positively, despite an expected significant decrease in ~~2023. Securing contracts for new mining projects~~full-year 2023 consolidated net income compared with 2022. In 2024 and ~~acquisitions of additional mineral interests could be accretive~~beyond, the Coal Mining segment expects increased profitability compared with anticipated full-year 2023 results due in part to improvements at Falkirk and MLMC. At Falkirk, the temporary price concessions end in June 2024. At MLMC, the cost per ton delivered is expected to moderate once the move to the ~~current forecast.~~new mine area is complete in the second half of 2023. In addition, certain costs incurred at MLMC in 2023 will be passed through to the customer and included in revenues in 2024. Earnings from the Sawtooth lithium project are also expected to contribute to improved results in 2024 and 2025 and more significantly when production commences at Thacker Pass in 2026.

~~Consolidated capital expenditures are expected to total approximately $61 million in 2022, including approximately $12 million for expenditures at~~ Mitigation Resources of North America®~~. The Company expects cash flow before financing activities~~ continues to build on the substantial foundation established over the past several years and currently has eight mitigation banks and four permittee-responsible mitigation projects located in ~~2022~~Tennessee, Mississippi, Alabama and Texas. Mitigation Resources was named a designated provider of abandoned mine land restoration by the State of Texas. It plans to ~~be significantly lower than in 2021 primarily due to increased capital expenditures.~~ provide ecological restoration services for abandoned surface mines as well as pursue additional environmental restoration projects during the remainder of 2023.

In 2023, the Company expects capital expenditures of approximately ~~$39~~$68 million, ~~excluding Minerals Management. Minerals Management is targeting investments~~which includes up to $20 million of ~~up $10 million. Future~~ investments at ~~Mineral Management are expected to continue to align with the Company’s strategy of selectively acquiring mineral and royalty interests with a balance of near-term cash-flow yields and~~

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~~long-term growth potential.~~Minerals Management. As a result of the forecasted capital expenditures and anticipated substantial decrease in net income, cash flow before financing activities in 2023 is expected to ~~return to a significant use of cash.~~be positive but decline significantly from 2022.

Table of September 30, 2022, the Company held an investment in Midwest AgEnergy, a North Dakota-based ethanol business. This investment is accounted for under the equity method. On October 26, 2022, Midwest AgEnergy announced that it has finalized an agreement under which the equity holders of Midwest AgEnergy, including NACCO, would sell their equity interests for cash. The transaction is expected to close before the end of 2022, however there can be no assurance that the transaction will be finalized in the anticipated timeframe or at all. The amount and timing of NACCO’s cash proceeds will be dependent on the terms of the transaction. The transaction is not expected to have a material impact on 2022 results of operations based on current estimates.Contents

Long-term Growth and Diversification

The Company is pursuing growth and diversification by strategically leveraging its core mining and natural resources management skills to build a strong portfolio of affiliated businesses. Management continues to be optimistic about the long-term ~~outlook for growth in~~outlook. In the ~~NAMining and~~ Minerals Management ~~segments and~~segment, as well as in the Company's Mitigation Resources ~~business. Each of these businesses continues to expand its pipeline of potential new projects with~~business, opportunities for growth ~~and diversification.~~

~~NAMining is pursuing growth and diversification by expanding the scope~~remain strong. Acquisitions of its business development activities to include potential customers who require a broad range of minerals and materials and by leveraging the Company’s core mining skills to expand the range of contract mining services it provides. The goal is to build NAMining into a leading provider of contract mining services for customers that produce a wide variety of minerals and materials. The Company believes NAMining can grow to be a substantial contributor to operating profit, delivering unlevered after-tax returns on invested capitaladditional mineral interests, an improvement in the ~~mid-teens as this business model matures~~outlook for the Company's largest Coal Mining segment customers and ~~achieves significant scale, but~~securing contracts for Mitigation Resources and new NAMining projects could be accretive to the ~~pace of growth will be dependent on the mix and scale of new projects.~~Company's outlook.

The Minerals Management segment continues to ~~grow and diversify by pursuing~~pursue acquisitions of mineral and royalty interests in the United States. The Minerals Management segment ~~will~~expects to benefit from the continued development of its mineral properties without additional capital investment, as ~~all further~~ development costs are borne entirely by third-party ~~producers who~~exploration and development companies that lease the minerals. This business model can deliver higher average operating margins over the life of a reserve than traditional oil and gas companies that bear the cost of exploration, production and/or development. Catapult, ~~Mineral Partners,~~ the Company’s business unit focused on managing and expanding the Company’s portfolio of oil and gas mineral and royalty interests, has developed a strong network to source and secure new acquisitions. The goal is to construct a high-quality diversified portfolio of oil and gas mineral and royalty interests in the United States that ~~deliver~~delivers near-term cash flow yields and long-term projected growth. The Company believes this business will provide unlevered after-tax returns on invested capital in the ~~low-to-mid-teens~~mid-teens as ~~the portfolio of reserves and mineral interests grows and~~ this business model matures.

The Company remains committed to expanding the NAMining business while improving profitability. NAMining intends to be a substantial contributor to operating profit over time. The pace of achieving that objective will depend on the execution and successful implementation of profit improvement initiatives in the aggregates operations, and the mix and scale of new projects. A number of initiatives are underway or in the planning stages that are expected to support the continuing improvement of financial results at these mining operations over time. Until profit improves at existing operations, NAMining has narrowed its business development efforts.

Sawtooth has a mining services agreement to provide comprehensive mining services as the exclusive contract miner for the Thacker Pass lithium project in northern Nevada, owned by Lithium Nevada Corp., a subsidiary of Lithium Americas Corp. (TSX: LAC) (NYSE: LAC). Lithium Americas controls the lithium reserves at Thacker Pass. On March 2, 2023, Lithium Americas announced that construction had commenced. Phase 1 production of lithium is projected to begin in the second half of 2026. Sawtooth began acquiring mining equipment for this project in the second quarter of 2023. Under the terms of the contract mining agreement, Lithium Americas will reimburse Sawtooth for these capital expenditures over a five-year period from the equipment acquisition date. Sawtooth will be reimbursed for all costs of mine construction plus a construction fee. The Company expects to continue to recognize moderate income prior to commencement of production in 2026. Once production commences, Sawtooth will receive a management fee per metric ton of lithium delivered. At maturity, this contract is expected to deliver fee income similar to a mid-sized management fee coal mine.

Mitigation Resources continues to expand its business, which creates and sells stream and wetland mitigation credits and provides services to those engaged in permittee-responsible ~~mitigation.~~mitigation as well as provides other environmental restoration services. This business offers an opportunity for growth and diversification in an industry where the Company has substantial knowledge and expertise and a strong reputation. ~~During the first nine months of 2022,~~ Mitigation Resources purchased property to establish a new mitigation bank north of Dallas/Fort Worth and established a joint venture to provide mitigation services for the Lake Ralph Hall project in Northern Texas. With these new 2022 projects, Mitigation Resources is involved in over 10 mitigation banks and permittee-responsible mitigation projects in Tennessee, Alabama, Mississippi and Texas and is making strong progress toward its goal ~~to be~~of becoming a top ten provider of stream and wetland mitigation services in the ~~Southeast~~southeastern United States. The Company believes that Mitigation Resources can provide solid rates of return on capital employed as this business matures.

The Company also continues to pursue activities which can strengthen the resiliency of its existing coal mining operations. The Company remains focused on managing coal production costs and maximizing efficiencies and operating capacity at mine locations to help customers with management fee contracts be more competitive. These activities benefit both customers and the Company's Coal Mining segment, as fuel cost is a significant driver for power plant dispatch. Increased power plant dispatch results in increased demand for coal by the Coal Mining segment's customers. Fluctuating natural gas prices, weather and availability of renewable energy sources, such as wind and solar, could affect the amount of electricity dispatched from coal-fired power plants. While the Company realizes the coal mining industry faces political and regulatory challenges and demand for coal is projected to decline over the longer-term, the Company believes coal should be an essential part of the energy mix in the United States for the foreseeable future.

The Company continues to look for ways to create additional value by utilizing its core mining competencies which include reclamation and permitting. One such way the Company may be able to utilize these skills is through development of utility-scale solar projects on reclaimed mining properties. Reclaimed mining properties offer large tracts of land that could be well-suited for solar and other energy-related projects. These projects could be developed by the Company itself or through joint

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ventures that include partners with expertise in energy development projects. In March 2023, the Company acquired 100% of the membership interests in the Marshall Mine, where Caddo Creek had been performing mine reclamation work. The Company is considering development of a utility-scale solar project at this location.

The Company is committed to maintaining a conservative capital structure as it continues to grow and diversify, while avoiding unnecessary risk. Strategic diversification will generate cash that can be re-invested to strengthen and expand the businesses. The Company also continues to maintain the highest levels of customer service and operational excellence with an unwavering focus on safety and environmental stewardship.

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FORWARD-LOOKING STATEMENTS

The statements contained in this Form 10-Q that are not historical facts are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. These forward-looking statements are made subject to certain risks and uncertainties, which could cause actual results to differ materially from those presented. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof. The Company undertakes no obligation to publicly revise these forward-looking statements to reflect events or circumstances that arise after the date hereof. Among the factors that could cause plans, actions and results to differ materially from current expectations are, without limitation: (1) changes to or termination of customer or other third-party contracts, or a customer or other third party default under a contract, (2) any customer's premature facility closure, (3) regulatory actions, including the United States Environmental Protection Agency's 2023 proposed rules relating to mercury and greenhouse gas emissions for coal-fired power plants, changes in mining permit requirements or delays in obtaining mining permits that could affect deliveries to customers, (4) a significant reduction in purchases by the Company's customers, including as a result of changes in coal consumption patterns of U.S. electric power generators, or changes in the power industry that would affect demand for the Company's coal and other mineral reserves, ~~(4)~~(5) changes in the prices of hydrocarbons, particularly diesel fuel, natural gas, natural gas liquids and oil, ~~(5)~~(6) failure or delays by the Company's lessees in achieving expected production of natural gas and other hydrocarbons; the availability and cost of transportation and processing services in the areas where the Company's oil and gas reserves are located; federal and state legislative and regulatory initiatives relating to hydraulic fracturing; and the ability of lessees to obtain capital or financing needed for well-development operations and leasing and development of oil and gas reserves on federal lands, ~~(6)~~(7) failure to obtain adequate insurance coverages at reasonable rates, ~~(7)~~(8) supply chain disruptions, including price increases and shortages of parts and materials, ~~(8) the impact of the COVID-19 pandemic, including any impact on suppliers, customers and employees,~~ (9) changes in tax laws or regulatory requirements, including the elimination of, or reduction in, the percentage depletion tax deduction, changes in mining or power plant emission regulations and health, safety or environmental legislation, (10) the ability of the Company to access credit in the current economic environment, or obtain financing at reasonable rates, or at all, and to maintain surety bonds for mine reclamation as a result of current market sentiment for fossil fuels, (11) impairment charges, (12) the effects of investors’ and other stakeholders’ increasing attention to environmental, social and governance ~~(“ESG”)~~ matters, (13) changes in costs related to geological and geotechnical conditions, repairs and maintenance, new equipment and replacement parts, fuel or other similar items, (14) ~~regulatory actions, changes in mining permit requirements or delays in obtaining mining permits that could affect deliveries to customers, (15)~~ weather conditions, extended power plant outages, liquidity events or other events that would change the level of customers' coal or aggregates requirements, ~~(16)~~(15) weather or equipment problems that could affect deliveries to customers, ~~(17)~~(16) changes in the costs to reclaim mining areas, ~~(18)~~(17) costs to pursue and develop new mining, mitigation, ~~and~~ oil and gas and solar development opportunities and other value-added service opportunities, ~~(19)~~(18) delays or reductions in coal or aggregates deliveries, ~~(20)~~(19) the ability to successfully evaluate investments and achieve intended financial results in new business and growth initiatives, ~~(21)~~(20) disruptions from natural or human causes, including severe weather, accidents, fires, earthquakes and terrorist acts, any of which could result in suspension of operations or harm to people or the environment, and ~~(22)~~(21) the ability to attract, retain, and replace workforce and administrative employees.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

As a “smaller reporting company” as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not required to provide this information.

Item 4. Controls and Procedures

Evaluation of disclosure controls and procedures: An evaluation was carried out under the supervision and with the participation of the Company's management, including the principal executive officer and the principal financial officer, of the effectiveness of the Company's disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, these officers have concluded that the Company's disclosure controls and procedures are effective.

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Changes in internal control over financial reporting: During the ~~third~~second quarter of ~~2022,~~2023, there have been no changes in the Company's internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

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PART II

OTHER INFORMATION

Item 1 Legal Proceedings

None.

Item 1A Risk Factors

During the quarter ended ~~September~~June 30, ~~2022,~~2023, there have been no material changes to the risk factors previously disclosed in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2021,~~2022, except as follows:

The ~~value~~coal mining industry is subject to ongoing complex governmental regulations and legislation that could adversely impact the Company’s long-term mining contracts and the Company’s results of ~~our investment in~~operations, liquidity, financial condition and cash flow.

The United States Environmental Protection Agency (the “EPA”) has a ~~private company involved~~comprehensive regulatory program to manage the disposal of coal combustion residuals (“CCR”) from coal-fired power plants as non-hazardous material under the Resource Conservation and Recovery Act (“RCRA”). Individual states administer some or all of the RCRA provisions. The North Dakota Department of Environmental Quality approved Falkirk’s customer's plan for an alternate disposal liner to store coal ash at the Coal Creek Station power plant. In the first quarter of 2023, the EPA proposed to deny the application. If denied, a new liner or new waste management unit(s) may need to be installed which could result in the ~~ethanol industry~~temporary suspension of operations at Coal Creek Station. To minimize any impact to operations, Coal Creek Station is moving forward with plans to dry CCR materials produced by the plant, reducing the need to utilize the lined area in question. Falkirk is the sole supplier of lignite coal to Coal Creek Station. Any suspension of operations at Coal Creek Station would eliminate the need for lignite coal during the suspension period. Any such suspension of operations at Coal Creek Station or any of the power plants supplied by the Company's mines could ~~decline, could be illiquid and could be volatile in terms of value and returns, which could adversely affect our~~have a material adverse effect on the Company’s business, financial condition and results of operations.

AsThe EPA also has a comprehensive regulatory program to manage airborne emissions from coal-fired power plants. During the first half of ~~September 30, 2022, we held~~2023, the EPA proposed updated rules related to mercury and greenhouse gas emissions from coal-fired power plants. The first update was to the Mercury Air Toxics Standard, or MATS. In this update, the EPA proposed to eliminate a ~~$20.0 million investment~~mercury emission standard for lignite-fired power plants that currently permits higher mercury emissions by lignite plants than other coal plants. In the event this rule is adopted as proposed, and not successfully legally challenged, it could result in ~~Midwest AgEnergy, a North Dakota-based ethanol business. Financial returns on ethanol investments are highly dependent on commodity prices, which are subject~~the closure of many lignite-fired power plants, potentially including all of those supplied by the Company. The second update was the EPA’s proposed new rule for greenhouse gas emissions from coal-fired power plants. In this proposed new rule, the EPA requires that power plant owners that intend to ~~significant volatility, uncertainty~~operate the plants beyond 2031 utilize controls including reduced levels of power generation, co-firing coal and ~~regional supply shortages. The valuation for this investment is based, in part, on an assumption that the private company will implement~~natural gas and installing carbon capture and ~~storage~~sequestration to capture carbon dioxide generated in the ethanol production process. This process increases the value of the ethanol produced by the private company. Should this capture process be delayed or not implemented, the value of this investment may be impaired.

On October 26, 2022, Midwest AgEnergy announced that it has finalized an agreement, under which the equity holders of Midwest AgEnergy, including NACCO, would sell their equity interests. The transaction is expected to close before the end of 2022, however there can be no assurance that the transaction will be finalized in the anticipated timeframe or at all. The amount and timing of NACCO’s cash proceeds will be dependent on the terms of the transaction. The transaction is not expected to have a material impact on 2022 results of operations based on current estimates.

If for any reason the proposed merger is not completed, this investment will continue to be accounted for under the equity method under which we report our proportionate share of the net earnings or losses of this private company as a component of Income before income tax provision. If the earnings or losses of and distributions from this investment is material in any year, those earnings or losses may have a material effect on our net income, cash flows, financial condition and liquidity. We do not control the day-to-day operations of this investment; however, how the company is managed could impact our results of operations and cash flows. Additionally, this business is subject to laws, regulations, market conditions and other risks inherent in its operations.

If the announced transaction is not finalized, this investment is non-marketable and we may not be able to achieve a return on our investment in a timely manner, if at all. Midwest Ag Energy’s operating agreement restricts the Company's ability to transfer the membership units, resulting in a liquidity discount. Since there is no active market for the exchangereduce greenhouse gas emissions. Each of these ~~securities, our ability to liquidate this investment will likely be dependent on a liquidity event. Valuations of privately-held companies are inherently complex and uncertain due to~~controls may impact the lack of readily available market data for such securities. If we determine that this investment has experienced a decline in value, we will be required to recognize an impairment charge in net income. Any of these factors could adversely impact our results of operations, our cash flows and the value of our investment.

MLMC is subject to risks associated with its capital investment, operating and equipment costs, growing use of alternative generation that competes with coal fired generation, changes in customer demand and inflationary adjustments.

~~The~~plant owners’ profitability of MLMC is subject to the risk of loss of investment in this operation, increases in the cost of mining, changes in customer demand, growing competition from alternative power generation that competes with coal-fired generation and the emergence of adverse mining conditions. At MLMC, the costs of mining operations are not reimbursed by MLMC's customer. As such, increased costs at MLMC or decreased revenues could materially reduce the Company's profitability. Any reduction in customer demand at MLMC, including reductions related to reduced mechanical availability of the customer’s power plant, would adversely affect the Company's operating results and could result in ~~significant impairments. MLMC has approximately $135 million~~the closure of long-lived assets, including property, plant and equipment and a coal supply agreement intangible asset, which are subject to periodic impairment analysis and review. Identifying and assessing whether impairment indicators exist, or if events or changes in circumstances have occurred, including assumptions about future power plant dispatch levels, changes in operating

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costs and other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual future operating results could differ significantly from these estimates, which may result in an impairment charge in a future period, which could have a substantial impact on the Company’s results of operations.

MLMC sells lignite at contractually agreed upon prices which are subject to changes in the level of established indices over time. As diesel fuel is heavily weighted among the indices used to determine the coal sales price, fluctuations in diesel fuel prices can result in significant fluctuations in earnings at MLMC.

MLMC delivers coal to the Red Hills Power Plant in Ackerman, Mississippi. The Red Hills Power Plant supplies electricity to TVA under a long-term power purchase agreement. MLMC’s contract with its customer runs through 2032. TVA’s power portfolio includes coal, nuclear, hydroelectric, natural gas and renewables. In 2019, TVA published its updated Integrated Resource Plan, which indicates plans to increase its reliance on solar power. A decrease in the number of days TVA dispatches the Red Hills Power Plant would reduce MLMC's customer's demand for coal. The decision of whichcoal-fired power plants, ~~to dispatch is determined~~potentially including all of those supplied by ~~TVA.~~

~~Choctaw Generation Limited Partnership ("CGLP") leases~~ the Red Hills Power Plant from a Southern Company subsidiary pursuant to a leveraged lease arrangement. CGLP's ability to make required payments to the Southern Company subsidiary is dependent on the operational performanceCompany. The closure of any of the ~~Red Hills Power Plant. During 2020, Southern~~power plants supplied by the Company revised the estimated cash flows to be received under the leveraged lease which resulted in a full impairment of the lease investment. If any future lease payment is not paid in full, the Southern Company subsidiary may be unable to make its corresponding payment to the holders of the underlying non-recourse debt related to the Red Hills Power Plant. Failure to make the required payment to the debtholders could represent an event of default that would give the debtholders the right to foreclose on, and take ownership of, the Red Hills Power Plant from the Southern Company subsidiary. A foreclosure of the Red Hills Power Plant could have a material adverse effect on ~~MLMC's~~the Company’s business, financial condition and results of operations and cash flows. Southern Company publicly disclosed that all required lease payments have been paid in full through December 31, 2021. On October 27, 2022, Southern Company disclosed in its Form 10-Q, that it provided notice to the lessee, CGLP, to terminate the related operating and maintenance agreement effective June 30, 2023. The parties to the lease agreement are currently negotiating a potential restructuring, which could result in rescission of the termination notice. The ultimate outcome of this matter cannot be determined at this time but could have a material impact on the Company's financial statements if the operating and maintenance agreement is terminated.operation.

~~Similar to~~See the ~~Company's unconsolidated mines, all production costs at MLMC are capitalized into inventory and recognized in cost~~Government Regulation Update on page 19 of sales as tons are delivered. In periods of limited or no deliveries, MLMC may be required to reduce its inventory carrying value using the lower of cost and net realizable value approach, which could adversely affect MLMC’s results of operations.

~~Changes in customer demand~~this Quarterly Report on Form 10-Q for any reason, including, but not limited to, reduced mechanical availability of the customer’s power plant, dispatch of power generated by other energy sources ahead of coal, fluctuations in demand due to unanticipated weather conditions, regulations or comparable policies which may promote planned and unplanned outages at the Red Hills Power Plant, economic conditions, including an economic slowdown and a corresponding decline in the use of electricity, governmental regulations and inflationary adjustments could have a material adverse effect on MLMC's financial condition, results of operations and cash flows.further information.

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Item 2 Unregistered Sales of Equity Securities and Use of Proceeds

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Issuer Purchases of Equity Securities (1)

Period

(a)
Total Number of Shares Purchased

(b)
Average Price Paid per Share

(d)

Maximum Dollar Value of Shares that May Yet Be Purchased Under the Program (1)

Month #1
(~~July~~April 1 to ~~31, 2022)~~30, 2023)

—

~~22,659,516~~20,000,000

Month #2
(~~August~~May 1 to 31, ~~2022)~~2023)

—

~~22,659,516~~20,000,000

Month #3
(~~September~~June 1 to 30, ~~2022)~~2023)

—

~~22,659,516~~20,000,000

Total

—

~~22,659,516~~20,000,000

(1) During 2021, the Company established a stock repurchase program allowing for the purchase of up to $20.0 million of the Company's Class A Common Stock outstanding through December 31, 2023. See Note 4 to the Unaudited Condensed Consolidated Financial Statements for further discussion of the Company's stock repurchase program.

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 is included in Exhibit 95 filed with this Quarterly Report on Form 10-Q for the period ended ~~September~~June 30, ~~2022.~~2023.

Item 5 Other Information

None.

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Item 6 Exhibits


Exhibit
Number*						Description of Exhibits

10.1						~~Second Amendment~~NACCO Industries, Inc.'s Amended and Restated Executive Long-Term Incentive Compensation Plan (effective March 1,2023) is incorporated herein by reference to ~~Coal Sales Agreement,~~Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by ~~and between~~ the ~~Falkirk Mining~~ Company and Rainbow Energy Center, LLC, dated August 5, 2022.**on May 1 6 , 2023, Commission File Number 1-9172.
31(i)(1)						Certification of J.C. Butler, Jr. pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act
31(i)(2)						Certification of Elizabeth I. Loveman pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act
32						Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, signed and dated by J.C. Butler, Jr. and Elizabeth I. Loveman
95						Mine Safety Disclosure Exhibit
101.INS						Inline XBRL Instance Document
101.SCH						Inline XBRL Taxonomy Extension Schema Document
101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document
104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

* Numbered in accordance with Item 601 of Regulation S-K.

** Filed herewith.

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Signatures

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


		NACCO Industries, Inc. (Registrant)
Date:	~~November~~August 2, ~~2022~~2023	/s/ Elizabeth I. Loveman
		Elizabeth I. Loveman
		Senior Vice President and Controller (principal financial and accounting officer)

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