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, ~~2020~~2021


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

Commission file 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 30, ~~2020: 5,477,225~~2021: 5,595,368

Number of shares of Class B Common Stock outstanding at ~~October~~July 30, ~~2020: 1,568,350~~2021: 1,566,643

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 ~~Statement~~s 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

1916

Item 3

Quantitative and Qualitative Disclosures About Market Risk

3331

Item 4

Controls and Procedures

Unregistered Sales of Equity Securities and Use of Proceeds

3832

Item 3

Defaults Upon Senior Securities

3832

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 2020		DECEMBER 31 2019			JUNE 30 2021		DECEMBER 31 2020
		(In thousands, except share data)					(In thousands, except share data)
ASSETS	ASSETS					ASSETS
Cash and cash equivalents	Cash and cash equivalents	$	97,567	$	122,892	Cash and cash equivalents	$	85,012	$	88,450
Trade accounts receivable, net	Trade accounts receivable, net	16,507		15,444		Trade accounts receivable, net	21,277		18,894
Accounts receivable from affiliates	Accounts receivable from affiliates	3,722		6,411		Accounts receivable from affiliates	6,933		4,764
Inventories	Inventories	42,433		40,465		Inventories	49,716		47,551

Refundable federal income taxes		25,379		8,928
Federal income tax receivable						Federal income tax receivable	9,334		17,615
Prepaid insurance						Prepaid insurance	7,977		2,564
Other current assets	Other current assets	12,996		6,528		Other current assets	9,064		8,308
Total current assets	Total current assets	198,604		200,668		Total current assets	189,313		188,146
Property, plant and equipment, net	Property, plant and equipment, net	156,598		138,061		Property, plant and equipment, net	175,553		172,417

Intangibles, net	Intangibles, net	35,599		37,902		Intangibles, net	33,437		35,330

Investments in unconsolidated subsidiaries	Investments in unconsolidated subsidiaries	25,545		24,611		Investments in unconsolidated subsidiaries	20,927		28,978

Operating lease right-of-use assets	Operating lease right-of-use assets	10,448		11,398		Operating lease right-of-use assets	9,594		10,324
Other non-current assets	Other non-current assets	39,108		32,133		Other non-current assets	45,215		40,984
Total assets	Total assets	$	465,902	$	444,773	Total assets	$	474,039	$	476,179
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Accounts payable	Accounts payable	$	13,603	$	9,374	Accounts payable	$	9,889	$	5,522
Accounts payable to affiliates	Accounts payable to affiliates	686		577		Accounts payable to affiliates	517		125
Revolving credit agreements	Revolving credit agreements	0		7,000		Revolving credit agreements	9,000		20,000
Current maturities of long-term debt	Current maturities of long-term debt	960		795		Current maturities of long-term debt	1,168		2,112
Asset retirement obligations	Asset retirement obligations	2,285		2,285		Asset retirement obligations	1,844		1,844
Accrued payroll	Accrued payroll	10,565		19,583		Accrued payroll	9,200		14,430
Deferred compensation		0		13,465
Deferred revenue		1,693		1,908

Other current liabilities	Other current liabilities	6,786		6,979		Other current liabilities	8,807		8,224
Total current liabilities	Total current liabilities	36,578		61,966		Total current liabilities	40,425		52,257
Long-term debt	Long-term debt	22,182		17,148		Long-term debt	21,805		24,353
Operating lease liabilities	Operating lease liabilities	11,494		12,448		Operating lease liabilities	10,479		11,196
Asset retirement obligations	Asset retirement obligations	40,811		34,574		Asset retirement obligations	41,095		39,888
Pension and other postretirement obligations	Pension and other postretirement obligations	7,430		8,807		Pension and other postretirement obligations	7,847		8,838
Deferred income taxes	Deferred income taxes	28,513		12,338		Deferred income taxes	14,784		17,550

Liability for uncertain tax positions						Liability for uncertain tax positions	9,413		9,413
Other long-term liabilities	Other long-term liabilities	12,405		8,100		Other long-term liabilities	12,464		12,060
Total liabilities	Total liabilities	159,413		155,381		Total liabilities	158,312		175,555
Stockholders' equity	Stockholders' equity					Stockholders' equity
Common stock:	Common stock:					Common stock:
Class A, par value $1 per share, 5,477,225 shares outstanding (December 31, 2019 - 5,397,458 shares outstanding)		5,477		5,397
Class B, par value $1 per share, convertible into Class A on a 1-for-one basis, 1,568,350 shares outstanding (December 31, 2019 - 1,568,670 shares outstanding)		1,568		1,569
Class A, par value $1 per share, 5,595,368 shares outstanding (December 31, 2020 - 5,489,615 shares outstanding)						Class A, par value $1 per share, 5,595,368 shares outstanding (December 31, 2020 - 5,489,615 shares outstanding)	5,595		5,490
Class B, par value $1 per share, convertible into Class A on a 1-for-one basis, 1,566,643 shares outstanding (December 31, 2020 - 1,568,210 shares outstanding)						Class B, par value $1 per share, convertible into Class A on a 1-for-one basis, 1,566,643 shares outstanding (December 31, 2020 - 1,568,210 shares outstanding)	1,567		1,568
Capital in excess of par value	Capital in excess of par value	9,381		8,911		Capital in excess of par value	12,928		10,895
Retained earnings	Retained earnings	301,045		284,852		Retained earnings	306,950		294,270
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(10,982)		(11,337)		Accumulated other comprehensive loss	(11,313)		(11,599)
Total stockholders' equity	Total stockholders' equity	306,489		289,392		Total stockholders' equity	315,727		300,624
Total liabilities and equity	Total liabilities and equity	$	465,902	$	444,773	Total liabilities and equity	$	474,039	$	476,179

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
		2020		2019		2020		2019			2021		2020		2021		2020
		(In thousands, except per share data)									(In thousands, except per share data)
Revenues	Revenues	$	32,295	$	32,603	$	105,294	$	114,052	Revenues	$	45,896	$	35,355	$	91,001	$	72,999
Cost of sales	Cost of sales	25,475		26,416		89,553		85,812		Cost of sales	36,911		31,515		74,324		64,078
Gross profit	Gross profit	6,820		6,187		15,741		28,240		Gross profit	8,985		3,840		16,677		8,921
Earnings of unconsolidated operations	Earnings of unconsolidated operations	15,145		17,438		44,926		47,851		Earnings of unconsolidated operations	13,542		13,778		28,884		29,781
Operating expenses	Operating expenses									Operating expenses
Selling, general and administrative expenses	Selling, general and administrative expenses	11,833		14,341		37,151		39,782		Selling, general and administrative expenses	12,878		12,591		26,641		25,318
Amortization of intangible assets	Amortization of intangible assets	734		715		2,303		2,243		Amortization of intangible assets	911		792		1,893		1,569
Gain on sale of assets		0		(94)		(247)		(131)
Loss (gain) on sale of assets										Loss (gain) on sale of assets	68		(247)		27		(247)
		12,567		14,962		39,207		41,894			13,857		13,136		28,561		26,640
Operating profit	Operating profit	9,398		8,663		21,460		34,197		Operating profit	8,670		4,482		17,000		12,062
Other (income) expense	Other (income) expense									Other (income) expense
Interest expense	Interest expense	336		230		1,069		683		Interest expense	359		330		715		733
Interest income	Interest income	(95)		(1,878)		(625)		(3,012)		Interest income	(100)		(129)		(220)		(530)
Income from other unconsolidated affiliates		(18)		(327)		(230)		(972)
Closed mine obligations	Closed mine obligations	395		383		1,219		1,079		Closed mine obligations	364		390		747		824
Gain on equity securities	Gain on equity securities	(35)		(108)		(351)		(1,067)		Gain on equity securities	(1,262)		(1,512)		(2,085)		(316)
Other, net	Other, net	(1,064)		(1,258)		(1,181)		(1,236)		Other, net	(127)		(181)		(257)		(329)
		(481)		(2,958)		(99)		(4,525)			(766)		(1,102)		(1,100)		382
Income before income tax provision		9,879		11,621		21,559		38,722
Income tax provision		1,857		1,357		1,321		5,465
Income before income tax provision (benefit)										Income before income tax provision (benefit)	9,436		5,584		18,100		11,680
Income tax provision (benefit)										Income tax provision (benefit)	2,931		(466)		2,634		(536)
Net income	Net income	$	8,022	$	10,264	$	20,238	$	33,257	Net income	$	6,505	$	6,050	$	15,466	$	12,216

Earnings per share:	Earnings per share:									Earnings per share:
Basic earnings per share	Basic earnings per share	$	1.14	$	1.47	$	2.88	$	4.77	Basic earnings per share	$	0.91	$	0.86	$	2.17	$	1.74
Diluted earnings per share	Diluted earnings per share	$	1.14	$	1.47	$	2.88	$	4.76	Diluted earnings per share	$	0.91	$	0.86	$	2.16	$	1.74

Basic weighted average shares outstanding	Basic weighted average shares outstanding	7,036		6,991		7,019		6,973		Basic weighted average shares outstanding	7,153		7,024		7,123		7,010
Diluted weighted average shares outstanding	Diluted weighted average shares outstanding	7,036		6,991		7,035		6,992		Diluted weighted average shares outstanding	7,153		7,024		7,147		7,034

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
		2020		2019		2020		2019			2021		2020		2021		2020
		(In thousands)									(In thousands)
Net income	Net income	$	8,022	$	10,264	$	20,238	$	33,257	Net income	$	6,505	$	6,050	$	15,466	$	12,216

Reclassification of pension and postretirement adjustments into earnings, net of $29 and $102 tax benefit in the three and nine months ended September 30, 2020, respectively, net of $21 and $66 tax benefit in the three and nine months ended September 30, 2019, respectively.		99		70		355		242
Reclassification of pension and postretirement adjustments into earnings, net of $42 and $85 tax benefit in the three and six months ended June 30, 2021, respectively, and net of $28 and $73 tax benefit in the three and six months ended June 30, 2020, respectively.										Reclassification of pension and postretirement adjustments into earnings, net of $42 and $85 tax benefit in the three and six months ended June 30, 2021, respectively, and net of $28 and $73 tax benefit in the three and six months ended June 30, 2020, respectively.	143		101		286		256
Total other comprehensive income	Total other comprehensive income	99		70		355		242		Total other comprehensive income	143		101		286		256
Comprehensive income	Comprehensive income	$	8,121	$	10,334	$	20,593	$	33,499	Comprehensive income	$	6,648	$	6,151	$	15,752	$	12,472

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
		2020		2019			2021		2020
		(In thousands)					(In thousands)
Operating activities	Operating activities					Operating activities

Net cash provided by operating activities		$	2,760	$	47,264
Net cash provided by (used for) operating activities						Net cash provided by (used for) operating activities	$	29,318	$	(12,489)

Investing activities	Investing activities					Investing activities
Expenditures for property, plant and equipment		(19,802)		(13,264)
Expenditures for property, plant and equipment and acquisition of mineral interests						Expenditures for property, plant and equipment and acquisition of mineral interests	(16,127)		(12,799)
Proceeds from the sale of property, plant and equipment	Proceeds from the sale of property, plant and equipment	550		4,475		Proceeds from the sale of property, plant and equipment	59		550
Purchase of equity securities	Purchase of equity securities	(2,000)		0		Purchase of equity securities	0		(2,000)
Other	Other	72		(20)		Other	(21)		(395)
Net cash used for investing activities	Net cash used for investing activities	(21,180)		(8,809)		Net cash used for investing activities	(16,089)		(14,644)

Financing activities	Financing activities					Financing activities
Additions to long-term debt	Additions to long-term debt	6,199		1,065		Additions to long-term debt	0		6,302
Reductions of long-term debt	Reductions of long-term debt	(1,057)		(498)		Reductions of long-term debt	(2,881)		(823)
Net reduction to revolving credit agreements		(7,000)		(4,000)
Net reductions to revolving credit agreements						Net reductions to revolving credit agreements	(11,000)		(2,000)
Cash dividends paid	Cash dividends paid	(4,045)		(3,808)		Cash dividends paid	(2,786)		(2,690)
Purchase of treasury shares	Purchase of treasury shares	(1,002)		(1,410)		Purchase of treasury shares	0		(1,002)

Net cash used for financing activities	Net cash used for financing activities	(6,905)		(8,651)		Net cash used for financing activities	(16,667)		(213)

Cash and cash equivalents	Cash and cash equivalents					Cash and cash equivalents
Total (decrease) increase for the period		(25,325)		29,804
Total decrease for the period						Total decrease for the period	(3,438)		(27,346)
Balance at the beginning of the period	Balance at the beginning of the period	122,892		85,257		Balance at the beginning of the period	88,450		122,892
Balance at the end of the period	Balance at the end of the period	$	97,567	$	115,061	Balance at the end of the period	$	85,012	$	95,546

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)
Balance, January 1, 2019		$	5,352	$	1,569	$	7,042	$	250,352	$	(13,611)	$	250,704
Stock-based compensation		102		—		795		—		—		897
Purchase of treasury shares		(36)		—		(1,264)		—		—		(1,300)
Net income		—		—		—		15,018		—		15,018
Cash dividends on Class A and Class B common stock: $0.1650 per share		—		—		—		(1,153)		—		(1,153)
Reclassification adjustment to net income, net of tax		—		—		—		—		101		101
Balance, March 31, 2019		$	5,418	$	1,569	$	6,573	$	264,217	$	(13,510)	$	264,267
Stock-based compensation		5		—		1,244		—		—		1,249
Purchase of treasury shares		(2)		—		(83)		—		—		(85)
Net income		—		—		—		7,975		—		7,975
Cash dividends on Class A and Class B common stock: $0.1900 per share		—		—		—		(1,327)		—		(1,327)
Reclassification adjustment to net income, net of tax		—		—		—		—		71		71
Balance, June 30, 2019		$	5,421	$	1,569	$	7,734	$	270,865	$	(13,439)	$	272,150
Stock-based compensation		5		—		2,119		—		—		2,124
Purchase of treasury shares		(1)		—		(24)		—		—		(25)
Net income		—		—		—		10,264		—		10,264
Cash dividends on Class A and Class B common stock: $0.1900 per share		—		—		—		(1,328)		—		(1,328)
Reclassification adjustment to net income, net of tax		—		—		—		—		70		70
Balance, September 30, 2019		$	5,425	$	1,569	$	9,829	$	279,801	$	(13,369)	$	283,255
															(In thousands, except per share data)
Balance, January 1, 2020	Balance, January 1, 2020	$	5,397	$	1,569	$	8,911	$	284,852	$	(11,337)	$	289,392	Balance, January 1, 2020	$	5,397	$	1,569	$	8,911	$	284,852	$	(11,337)	$	289,392
Stock-based compensation	Stock-based compensation	88		—		377		—		—		465		Stock-based compensation	88		—		377		—		—		465
Purchase of treasury shares	Purchase of treasury shares	(32)		—		(970)		—		—		(1,002)		Purchase of treasury shares	(32)		—		(970)		—		—		(1,002)
Net income	Net income	—		—		—		6,166		—		6,166		Net income	—		—		—		6,166		—		6,166
Cash dividends on Class A and Class B common stock: $0.1900 per share	Cash dividends on Class A and Class B common stock: $0.1900 per share	—		—		—		(1,339)		—		(1,339)		Cash dividends on Class A and Class B common stock: $0.1900 per share	—		—		—		(1,339)		—		(1,339)
Reclassification adjustment to net income, net of tax	Reclassification adjustment to net income, net of tax	—		—		—		—		155		155		Reclassification adjustment to net income, net of tax	—		—		—		—		155		155
Balance, March 31, 2020	Balance, March 31, 2020	$	5,453	$	1,569	$	8,318	$	289,679	$	(11,182)	$	293,837	Balance, March 31, 2020	$	5,453	$	1,569	$	8,318	$	289,679	$	(11,182)	$	293,837
Stock-based compensation	Stock-based compensation	10		—		624		—		—		634		Stock-based compensation	10		—		624		—		—		634

Net income	Net income	—		—		—		6,050		—		6,050		Net income	—		—		—		6,050		—		6,050
Cash dividends on Class A and Class B common stock: $0.1925 per share	Cash dividends on Class A and Class B common stock: $0.1925 per share	—		—		—		(1,351)		—		(1,351)		Cash dividends on Class A and Class B common stock: $0.1925 per share	—		—		—		(1,351)		—		(1,351)
Reclassification adjustment to net income, net of tax	Reclassification adjustment to net income, net of tax	—		—		—		—		101		101		Reclassification adjustment to net income, net of tax	—		—		—		—		101		101
Balance, June 30, 2020	Balance, June 30, 2020	$	5,463	$	1,569	$	8,942	$	294,378	$	(11,081)	$	299,271	Balance, June 30, 2020	$	5,463	$	1,569	$	8,942	$	294,378	$	(11,081)	$	299,271

Balance, January 1, 2021														Balance, January 1, 2021	$	5,490	$	1,568	$	10,895	$	294,270	$	(11,599)	$	300,624
Stock-based compensation	Stock-based compensation	13		—		439		—		—		452		Stock-based compensation	92		—		923		—		—		1,015

Conversion of Class B to Class A shares	Conversion of Class B to Class A shares	1		(1)		—		—		—		0		Conversion of Class B to Class A shares	1		(1)		—		—		—		0
Net income	Net income	—		—		—		8,022		—		8,022		Net income	—		—		—		8,961		—		8,961
Cash dividends on Class A and Class B common stock: $0.1925 per share	Cash dividends on Class A and Class B common stock: $0.1925 per share	—		—		—		(1,355)		—		(1,355)		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	Reclassification adjustment to net income, net of tax	—		—		—		—		99		99		Reclassification adjustment to net income, net of tax	—		—		—		—		143		143
Balance, September 30, 2020		$	5,477	$	1,568	$	9,381	$	301,045	$	(10,982)	$	306,489
Balance, March 31, 2021														Balance, March 31, 2021	$	5,583	$	1,567	$	11,818	$	301,857	$	(11,456)	$	309,369
Stock-based compensation														Stock-based compensation	12		—		1,110		—		—		1,122

Net income														Net income	—		—		—		6,505		—		6,505
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	—		—		—		(1,412)		—		(1,412)
Reclassification adjustment to net income, net of tax														Reclassification adjustment to net income, net of tax	—		—		—		—		143		143
Balance, June 30, 2021														Balance, June 30, 2021	$	5,595	$	1,567	$	12,928	$	306,950	$	(11,313)	$	315,727

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, ~~2020~~2021

(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, “NACCO Industries, Inc. and Subsidiaries”~~ or the ~~“Company”~~"Company"). ~~Intercompany accounts~~NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and ~~transactions are eliminated in consolidation.~~environmental solutions through its robust portfolio of NACCO ~~is the public holding company for The North American Coal Corporation~~® ~~("NACoal").~~Natural Resources businesses. The Company ~~has~~operates under 3 ~~operating~~business segments: Coal Mining, North American Mining ~~(“NAMining”~~("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines for power generation companies and an activated carbon producer. The NAMining segment is a trusted mining partner for producers of aggregates, lithium and other minerals. The Minerals Management segment promotes the development of mineral interests. In addition, Mitigation Resources of North America® provides stream and wetland mitigation solutions.

The Company also has unallocated items not directly attributable to a reportable segment. Intercompany accounts and transactions are eliminated in consolidation. See Note 98 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® ("NACoal"), operates surface coal mines under long-term contracts with power generation companies and an activated carbon producer pursuant to a service-based business model. Coal is surface-mined in North Dakota, Texas, Mississippi, Louisiana and on the Navajo Nation in New Mexico. Each mine is fully integrated with its customer's operations.

During the ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, the Company's operating coal mines were: Bisti Fuels ~~LLC (“Bisti”), Caddo Creek Resources~~ Company, LLC (“~~Caddo Creek”~~Bisti”), The Coteau Properties Company (“Coteau”), Coyote Creek Mining Company, LLC (“Coyote Creek”), Demery Resources Company, LLC (“Demery”), The Falkirk Mining Company (“Falkirk”), Mississippi Lignite Mining Company (“MLMC”) and The Sabine Mining Company (“Sabine”).

~~On September 30, 2020, Caddo Creek’s customer, a division~~Falkirk operates the Falkirk Mine in North Dakota. Falkirk is the sole supplier of ~~Cabot Corporation, entered into a long-term supply agreement with a subsidiary of Advanced Emissions Solutions (“AES”) as well as an agreement for~~lignite coal to the ~~sale of the Marshall Mine, operated by Caddo~~Coal Creek Station power plant pursuant to a ~~subsidiary~~contract under which Falkirk also supplies approximately 0.3 million tons of ~~AES. AES~~lignite coal per year to Spiritwood Station power plant. Coal Creek Station and Spiritwood Station are owned by Great River Energy (“GRE”). In May 2020, GRE announced its intent to sell or retire Coal Creek Station in the second half of 2022 and modify Spiritwood Station to be fueled by natural gas.

On June 30, 2021, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct current transmission line to Bismarck, North Dakota-based Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. The transaction between GRE and Rainbow Energy is subject to the satisfaction of certain conditions, including regulatory approvals associated with the sale of Coal Creek Station and the related transmission assets and the posting of a performance bond related to final mine reclamation. If the conditions are satisfied, the transaction is expected to close before the ~~Marshall Mine. Caddo~~end of 2021.

Upon completion of the sale of Coal Creek Station, the existing Coal Sales Agreement, the existing Mortgage and Security Agreement and the existing Option Agreement between GRE and Falkirk will be terminated. Falkirk and GRE have entered into a ~~contract with~~termination and release of claims agreement. Upon completion of the sale of Coal Creek Station, GRE will pay Falkirk $14.0 million in cash, as well as transfer ownership of an office building located in Bismarck, North Dakota, and convey membership units in Midwest AgEnergy to NACoal. NACCO currently holds a ~~subsidiary of AES to perform the required mine reclamation. In 2019, total tons delivered by the Coal Mining segment was 34.6~~$5.0 million ~~tons, of~~investment in Midwest AgEnergy, which ~~0.2 million tons related to Caddo Creek.~~operates two ethanol facilities in North Dakota.

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years from the effective date of the CSA, but the CSA may be extended or terminated early under certain circumstances. If Rainbow Energy terminates the CSA and closes Coal Creek Station before 2027, Falkirk will be entitled to an additional payment from GRE under the terms of the termination and release of claims agreement. The additional payment amount ranges from $8 million if the closure occurs before 2024 to $2 million if the closure occurs in 2026. 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 current fee levels, and thereafter adjusts annually according to specific indices which track broad measures of U.S. inflation.

Bisti supplies the Four Corners Power Plant through its contract mining agreement with the Navajo Transitional Energy Company ("NTEC"). On June 17, 2021, the Company received notification that the contract mining agreement between Bisti and NTEC will be terminated effective September 30, 2021. As required under the agreement, it is anticipated NTEC will pay NACCO a termination fee of approximately $10 million. NTEC will assume control and responsibility for operation of the Navajo Mine upon termination of the contract mining agreement. All liabilities, including mine reclamation, are the responsibility of NTEC.

Sabine operates the Sabine Mine in Texas. All production from ~~the~~ Sabine ~~Mine~~ is delivered to Southwestern Electric Power Company's (“SWEPCO”) Henry W. Pirkey ~~Plant. The~~Plant (the “Pirkey Plant”). SWEPCO is an American Electric Power (“AEP”) company. In November 2020, AEP announced it intends to retire the Pirkey ~~power plant has been dispatched at a lower rate during~~Plant in 2023. SWEPCO expects deliveries from Sabine to continue until the first ~~nine months of 2020 compared with the first nine months of 2019, resulting in a 43% reduction in tons delivered in 2020 compared with 2019. During the third~~ quarter of ~~2020, Sabine’s customer reduced its expected future annual deliveries~~2023 at which time Sabine expects to be between 1.4 million and 1.7 million tons of lignite coal. Sabine historically has delivered between 2.5 million and 3.5 million tons of lignite coal annually, including 2.6 million tons in 2019 and 3.8 million tons in 2018.

The contract mining agreement between Camino Real Fuels, LLC (“Camino Real”) and its customer, Dos Republicas Coal Partnership (“DRCP”), terminated effective July 1, 2020 as a result of the unexpected termination by Comisión Federal de Electricidad (“CFE”) of its coal supply contract with an affiliate of DRCP. The termination of the contract between CFE and DRCP eliminated DRCP’s needbegin final reclamation. Funding for ~~coal from Camino Real's Eagle Pass Mine, and resulted in~~ mine ~~closure. Mine~~ reclamation is the responsibility of ~~DRCP. Camino Real has no legal obligation~~SWEPCO.

Coteau operates the Freedom Mine in North Dakota. All coal production from the Freedom Mine is delivered to ~~perform mine reclamation.~~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 ~~Company received certain inventory as well as~~Synfuels Plant is a ~~securitized note~~coal gasification plant that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. In November 2020, Basin Electric informed Coteau that it is considering changes that may result in ~~settlement~~modifications to its Synfuels Plant that could potentially reduce or eliminate coal requirements at the Synfuels Plant beginning in 2026. Basin Electric indicated that if it decides to proceed with any changes that could reduce or eliminate the use of coal, the ~~outstanding receivable balance due from DRCP. During~~feedstock change is not expected to occur before 2026. In June 2021, Basin Electric announced it was also evaluating the ~~fourth quarter of 2020, the Company received payment~~Synfuels Plant for ~~the outstanding balance on the securitized note, which was $2.3 million as of September 30, 2020, and is included within Other current assets on the Unaudited Condensed Consolidated Balance Sheet.~~possible sale.

At all operating coal mines other than MLMC, 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 ~~providing~~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 steady 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. See Note 76 for further discussion of Coyote Creek's guarantees.

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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 expense line on the Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. ~~All of~~See Note 6 for further information on the Unconsolidated ~~Subsidiaries are accounted for under the equity method. See Note 7 for further discussion.~~

Camino Real and Caddo Creek previously met the definition of a variable interest entity of which the Company was not the primary beneficiary and therefore NACCO did not consolidate the results of operations within its financial statements. As a result of the events described above, Camino Real and Caddo Creek are no longer VIEs. Camino Real’s financial position was consolidated within NACCO’s financial statements beginning on June 30, 2020. Camino Real’s results of operations for the three months ended September 30, 2020 did not materially change the Company's Unaudited Condensed Consolidated Statements of Operations. Caddo Creek’s financial position will be consolidated within NACCO’s financial statements beginning in the fourth quarter of 2020. The consolidation of these entities will not materially change the Company’s Unaudited Condensed Consolidated Balance Sheet.Subsidiaries.

~~As of September 30, 2020, all of the Liberty Fuels~~Caddo Creek Resources Company, LLC ~~mine areas have been reclaimed~~(“Caddo Creek”) ceased all mining and ~~final~~delivery of lignite and commenced mine reclamation ~~activities, primarily monitoring, will continue until final bond release.~~in the fourth quarter of 2020. The financial results of Caddo Creek are consolidated within NACCO's financial statements for the six months ended June 30, 2021. Prior to entering into reclamation, Caddo Creek met the definition of a VIE; therefore, the financial results of Caddo Creek are reported as Earnings of unconsolidated operations for the three and six months ended June 30, 2020. The reclamation at Caddo Creek is expected to be substantially complete by June 30, 2022.

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~~Centennial Natural Resources (“Centennial”), located in Alabama, ceased coal production at the end of 2015.~~

NAMining Segment

The NAMining segment provides value-added contract mining and other services for producers of aggregates, lithium and other minerals. The segment is a primary platform for the Company’s growth and diversification of mining activities outside of the 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. NAMining operates primarily at limestone quarries in Florida, but is focused on expanding outside of Florida, ~~and into~~ mining materials other than ~~limestone.~~

~~During 2019,~~limestone and expanding the ~~Company~~scope of mining operations provided to its customers. In the second quarter of 2021, NAMining entered into a one-year mining ~~agreement, through~~services contract with an existing customer for a ~~new subsidiary, Sawtooth Mining, to~~sand and gravel quarry in Indiana. In addition, NAMining will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada. The Thacker Pass Project is 100% owned by Lithium Nevada Corp. Sawtooth Mining will provide comprehensive mining services and certain equipment during the 20-year contract term. During the development of the project, Sawtooth Mining will provide Lithium Nevada $3.5 million in cash to assist in project development, of which $3.0 million and $1.5 million has been provided as of September 30, 2020 and December 31, 2019, respectively, and included within Other non-current assets on the Unaudited Condensed Consolidated Balance Sheets. Lithium Nevada is in the process of securing permits and currently expects to commence construction in 2021 and production of lithium products in 2023.

NAMining utilizes both fixed price and ~~cost plus~~ 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 76 for further discussion.

Minerals Management Segment

The Minerals Management segment ~~promotes~~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 ~~development of the Company’s~~rights to explore, develop, mine, produce, market and sell gas, oil, and coal ~~reserves, generating income~~in exchange for royalty payments based on the lessees' sales of those minerals. During 2021 and 2020, the Minerals Management segment acquired mineral interests, primarily ~~from royalty-based lease~~in the Eagle Ford and Permian Basins in Texas and intends to make future acquisitions of mineral and royalty interests that meet the Company’s acquisition criteria as part of its growth strategy.

In the second quarter of 2021, the Minerals Management segment, through its Catapult Mineral Partners (“Catapult”) business, acquired a combination of mineral and overriding royalty interests in the Eagle Ford Basin, which includes approximately 14.1 thousand gross acres and 1.7 thousand net royalty acres, for $4.7 million. Under the terms of the transaction, Catapult will make additional payments ~~from third parties.~~ for each additional well developed on the acquired assets at the end of 2021 and 2022 of up to a maximum of $0.6 million per year, or an additional $1.2 million of additional payments in total. Catapult also completed a small acquisition of royalty interests in the Delaware Basin in the second quarter of 2021 for a purchase price of $0.3 million.

The Company’s ~~gas, oil~~legacy royalty and ~~undeveloped coal reserves~~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 and coalbed methane and natural gas) and North Dakota ~~(coal)~~(coal, oil and natural gas).

The majority of the Company’s ~~existing~~legacy reserves were acquired as part of its historical coal mining operations. The Minerals Management segment derives income primarily by entering into contracts with third-party operators, granting them the rights to explore, produce and sell natural resources in exchange for royalty payments based on the lessees' sales of natural gas and, to a lesser extent, oil and coal. Specialized employees in the Minerals Management segment also provide surface and mineral acquisition and lease maintenance services related to Company operations.

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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, ~~2020,~~2021, the results of its operations, comprehensive income, cash flows and changes in equity for the ~~nine~~six months ended ~~September~~June 30, ~~2020~~2021 and ~~2019~~2020 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, ~~2019.~~2020.

The balance sheet at December 31, ~~2019~~2020 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 prior period Unaudited Condensed Consolidated Financial Statements have been reclassified to conform to the current period's presentation.

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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 or mine area 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.

During 2020, Caddo Creek entered into 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 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 the transfer of control 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.

At NAMining, ~~entities,~~ the management service to oversee the operation of the equipment and delivery of ~~limestone~~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 ~~and variances in reimbursable costs~~ primarily due to increases and decreases in activity levels on individual ~~contracts.~~contracts and variances in reimbursable costs.

The ~~Company~~Minerals Management segment enters into ~~royalty~~ contracts which grant 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.

Under these ~~royalty~~ contracts, granting exclusive right, title, and interest in and to minerals, if any, 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 pricing provisions of royalty contracts are customary in the industry. Up-front lease bonus payments represent the fixed portion of the transaction price ~~will be~~and are recognized over the primary term of the contract, which is generally five years.

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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 ~~coal~~ volumes or MMBtu delivered, ~~or limestone yards,~~ 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.

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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.~~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 generally 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.

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 "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 June 30, 2021 and 2020, royalty income recognized in the reporting periods related to performance obligations satisfied in prior reporting periods was immaterial.

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 98 to the Unaudited Condensed Consolidated Financial Statements for further discussion of segment reporting.

~~The following table disaggregates revenue by major sources:~~

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
Major Goods/Service Lines 2020 2019 2020 2019
Coal Mining $ 20,395 $ 18,799 $ 62,896 $ 58,119
NAMining 9,443 8,993 33,115 30,496
Minerals Management 2,722 5,022 9,950 25,950
Unallocated Items 904 52 1,257 726
Eliminations (1,169) (263) (1,924) (1,239)
Total revenues $ 32,295 $ 32,603 $ 105,294 $ 114,052
Timing of Revenue Recognition
Goods transferred at a point in time $ 19,871 $ 18,049 $ 61,131 $ 56,012
Services transferred over time 12,424 14,554 44,163 58,040
Total revenues $ 32,295 $ 32,603 $ 105,294 $ 114,052


	THREE MONTHS ENDED				SIX MONTHS ENDED
	JUNE 30				JUNE 30
	2021		2020		2021		2020
Timing of Revenue Recognition
Goods transferred at a point in time	$	20,117	$	20,976	$	41,495	$	41,260
Services transferred over time	25,779		14,379		49,506		31,739
Total revenues	$	45,896	$	35,355	$	91,001	$	72,999

Contract Balances

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

Contract balances
Trade accounts receivable, net Contract liability (current) Contract liability (long-term)
Balance, January 1, 2020 $ 15,444 $ 944 $ 2,153
Balance, September 30, 2020 16,507 941 1,448
Increase (decrease) $ 1,063 $ (3) $ (705)


	Contract balances
	Trade accounts receivable, net		Contract asset (long-term)		Contract liability (current)		Contract liability (long-term)
Balance, January 1, 2021	$	18,894	$	4,984	$	941	$	3,626
Balance, June 30, 2021	21,277		5,321		868		4,113
Increase (decrease)	$	2,383	$	337	$	(73)	$	487

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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 five years. Therefore, at the time any such up-front payment is received, a contract liability is recorded which represents deferred revenue. The difference between the opening and closing balance of this contract liability, which is shown above, primarily results from the difference between new lease bonus payments received and amortization of up-front lease bonus payments received in previous periods.

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The amount of revenue recognized in both of the three months ended ~~September~~June 30, ~~2020~~2021 and ~~September 30, 2019~~2020 that was included in the opening contract liability was ~~$0.2 million and $0.1 million, respectively.~~$0.3 million. The amount of revenue recognized in both of the ~~nine~~six months ended ~~September~~June 30, ~~2020~~2021 and ~~September 30, 2019~~2020 that was included in the opening contract liability was ~~$0.7 million and~~ $0.5 ~~million, respectively.~~million. 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 five years. The Company expects to recognize an additional ~~$0.2~~$0.5 million in the remainder of ~~2020, $0.9 million in~~ 2021, ~~$0.7~~$4.0 million in 2022, $0.3 million in 2023, and $0.1 million in 2024 related to the contract liability remaining at ~~September~~June 30, ~~2020.~~2021. The difference between the opening and closing balances of the Company’s accounts receivable, contract assets and contract liabilities results from the timing difference between the Company’s performance and the customer’s payment. ~~Contracts with payments in arrears are recognized as receivables.~~

The Company has 0 contract assets recognized from the costs to obtain or fulfill a contract with a customer.

NOTE 3—Inventories

Inventories are summarized as follows:


		SEPTEMBER 30 2020		DECEMBER 31 2019			JUNE 30 2021		DECEMBER 31 2020
Coal	Coal	$	12,161	$	15,700	Coal	$	16,025	$	17,695
Mining supplies	Mining supplies	30,272		24,765		Mining supplies	33,691		29,856
Total inventories	Total inventories	$	42,433	$	40,465	Total inventories	$	49,716	$	47,551

NOTE 4—~~Leases~~

NACCO adopted ASU 2016-02, Leases (Topic 842), on January 1, 2019. The most significant effect to the Unaudited Condensed Consolidated Balance Sheets relates to the recognition of new right-of-use assets and lease liabilities for operating leases of real estate, mining and other equipment that expire at various dates through 2031. The majority of the Company's leases are operating leases. See the table below for further information on the balances included in the Unaudited Condensed Consolidated Balance Sheets. Several leases include renewal or fair value purchase options, which are not recognized on the Unaudited Condensed Consolidated Balance Sheets. The Company's lease agreements do not contain lease payments that depend on an index or a rate, as such, minimum lease payments do not include variable lease payments.

~~Leased assets and liabilities include the following:~~

Description Location SEPTEMBER 30
2020 DECEMBER 31
2019
Assets
   Operating Operating lease right-of-use assets $ 10,448 $ 11,398
   Finance Property, plant and equipment, net (a) $ 144 $ 544
Liabilities
Current
   Operating Other current liabilities $ 1,296 $ 1,318
   Finance Current maturities of long-term debt $ 44 $ 558
Noncurrent
   Operating Operating lease liabilities $ 11,494 $ 12,448
   Finance Long-term debt $ 103 $ 85

~~(a)~~ ~~Finance leased assets are recorded net of accumulated amortization of less than $0.1 million and $1.9 million as of September 30, 2020 and December 31, 2019, respectively.~~

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~~The components of lease expense were as follows:~~

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
Description Location 2020 2019 2020 2019
Lease expense
Operating lease cost Selling, general and administrative expenses $ 499 $ 569 $ 1,513 $ 1,783
Finance lease cost:
Amortization of leased assets Cost of sales 10 104 113 300
Interest on lease liabilities Interest expense
2 4 8 10
Variable lease expense Selling, general and administrative expenses 157 141 444 416
Short-term lease expense Selling, general and administrative expenses 89 79 248 242
Total lease expense $ 757 $ 897 $ 2,326 $ 2,751

~~Future minimum finance and operating lease payments were as follows at September 30, 2020:~~

Finance
Leases Operating
Leases Total
Remainder of 2020 $ 13 $ 532 $ 545
2021 49 2,113 2,162
2022 49 2,162 2,211
2023 28 1,685 1,713
2024 12 1,660 1,672
Subsequent to 2024 7 9,421 9,428
Total minimum lease payments $ 158 $ 17,573 $ 17,731
Amounts representing interest 11 4,783
Present value of net minimum lease payments $ 147 $ 12,790

As most of the Company's leases do not provide an implicit rate, the Company determines the incremental borrowing rate based on the information available at the lease commencement date in determining the present value of lease payments. The Company considers its credit rating and the current economic environment in determining this collateralized rate. The assumptions used in accounting for ASC 842 were as follows:

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
Lease term and discount rate 2020 2019 2020 2019
Weighted average remaining lease term (years)
   Operating 9.19 9.76 9.19 9.76
   Finance 3.47 1.95 3.47 1.95
Weighted average discount rate
   Operating 7.01 % 6.99 % 7.01 % 6.99 %
   Finance 3.96 % 5.36 % 3.96 % 5.36 %

~~The following table details cash paid for amounts included in the measurement of lease liabilities:~~

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
Cash paid for amounts included in the measurement of lease liabilities 2020 2019 2020 2019
Operating cash flows from operating leases $ 532 $ 608 $ 1,646 $ 1,768
Operating cash flows from finance leases $ 2 $ 4 $ 8 $ 10
Financing cash flows from finance leases $ 9 $ 115 $ 551 $ 347

~~Table of Contents~~

~~NOTE 5—~~Stockholders' Equity

Stock Repurchase Program: ~~On November 6,~~During 2019, the Company's Board of Directors approved a stock purchase program ("2019 Stock Repurchase Program") providing for the purchase of up to $25 million of the Company's outstanding Class A Common Stock through December 31, 2021. ~~NACCO's previous repurchase program ("2018 Stock Repurchase Program") would have expired on December 31, 2019 but was terminated and replaced by the 2019 Stock Repurchase Program.~~ As a result of the uncertainty surrounding the COVID-19 pandemic, the Company suspended repurchasing shares under the 2019 Stock Repurchase Program in March 2020. Prior to the decision to cease share repurchases, the Company repurchased 32,286 shares of Class A Common Stock under the 2019 Stock Repurchase Program for an aggregate purchase price of $1.0 million during the ~~nine~~six months ended ~~September~~June 30, 2020. During the three and nine months ended September 30, 2019, the Company repurchased 525 and 39,049 shares, respectively, of Class A Common Stock under the 2018 Stock Repurchase Program for an aggregate purchase price of less than $0.1 million and $1.4 million, respectively.

The timing and amount of any repurchases under the 2019 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, market conditions for the Company's Class A Common Stock and other legal and contractual restrictions. The 2019 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 2019 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.

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NOTE 6—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, 2020									June 30, 2021
Assets:	Assets:									Assets:
Equity securities	Equity securities	$	12,238	$	12,238	$	0	$	0	Equity securities	$	14,655	$	14,655	$	0	$	0

		$	12,238	$	12,238	$	0	$	0		$	14,655	$	14,655	$	0	$	0

		December 31, 2019									December 31, 2020
Assets:	Assets:									Assets:
Equity securities	Equity securities	$	10,120	$	10,120	$	0	$	0	Equity securities	$	13,164	$	13,164	$	0	$	0
		$	10,120	$	10,120	$	0	$	0		$	13,164	$	13,164	$	0	$	0

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 2019, Bellaire established a $5.0 million mine water treatment trust (the "Mine Water Treatment Trust") to provide a financial assurance mechanism 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 gain of ~~$0.5~~$0.7 million and ~~$0.4~~$1.0 million during the three and six months ended June 30, 2021, respectively, and a gain of $1.1 million and a loss of $0.1 million in the three and ~~nine~~six months ended ~~September~~June 30, 2020, ~~respectively, and a gain of $0.1 million and $1.1 million in the three and nine months ended September 30, 2019,~~ respectively, related to the Mine Water Treatment Trust.

During the second quarter of 2020, 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~~gain of ~~$0.5~~$0.6 million and ~~$0.1~~$1.1 million induring the three and ~~nine~~six months ended ~~September~~June 30, 2021, respectively, and a gain of $0.4 million in both the three and six months ended June 30, 2020 ~~respectively,~~ related to the investment in these equity securities.

~~Table of Contents~~

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

There were no transfers into or out of Levels 1, 2 or 3 during the ~~three and nine~~six months ended ~~September~~June 30, ~~2020~~2021 and ~~2019.~~2020.

NOTE 7—6—Unconsolidated Subsidiaries

Each of ~~NACoal's~~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 ~~other than at Coyote Creek,~~generally without recourse to NACCO and NACoal. Although NACoal 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 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 ~~$25.5~~$20.9 million and ~~$24.6~~$29.0 million at ~~September~~June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively. The Company's maximum risk of loss relating to these entities is limited to its invested capital, which was ~~$4.4~~$5.5 million and ~~$5.0~~$6.5 million at ~~September~~June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively. Earnings of unconsolidated operations were $13.5 million and $28.9 million during the three and six months ended June 30, 2021, respectively, and $13.8 million and $29.8 million during the three and six months ended June 30, 2020, respectively.

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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 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.

~~Summarized financial information for the Unconsolidated Subsidiaries is as follows:~~

THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
2020 2019 2020 2019
Gross profit $ 18,046 $ 20,059 $ 49,792 $ 53,826
Income before income taxes $ 15,629 $ 17,827 $ 45,673 $ 49,080

NOTE 8—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 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.

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NOTE 9—8—Business Segments

The ~~Company's~~Company’s operating segments are: (i) Coal Mining, (ii) NAMining and (iii) Minerals Management. While the Company continues to pursue opportunities to add new coal mining operations to the Coal Mining segment, the NAMining segment serves as the platform for pursuing non-coal mining projects and the Minerals Management segment promotes the development of the Company's gas, oil and coal reserves.

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 ~~also~~ has ~~unallocated~~ items not directly attributable to a reportable segment ~~which~~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 ~~the Company’s mitigation banking business,~~ Mitigation Resources of North America® (“~~MRNA”~~Mitigation Resources”), and Bellaire. ~~MRNA~~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. ~~Transactions between segments are accounted for as third-party arrangements for purposes of presenting segment results of operations and are eliminated in consolidation.~~

As of January 1, 2020, the Company retrospectively changed its computation of segment operating profit to reclassify certain expenses, primarily related to executive and board compensation. These expenses are now included in unallocated items. The change in segment reporting reflected a decision to evaluate the financial performance of the Company’s segments excluding executive and board compensation. All prior period segment information has been reclassified to conform to the new presentation. This segment reporting change has no impact on consolidated operating results.

All financial statement line items below operating profit (other income including interest expense and interest income, the provision for income taxes and net income) are presented and discussed within this Form 10-Q on a consolidated basis. ~~Included within other income on the line Income from other unconsolidated affiliates within the Unaudited Condensed Consolidated Statements~~

Table of Operations is the financial results of NoDak Energy Services, LLC ("NoDak"). NoDak operated and maintained a coal drying system at a customer’s power plant. The NoDak contract expired in the first quarter of 2020.Contents

See Note 1 for additional discussion of the Company's reportable segments. The following tables present revenue, operating profit, depreciation expense and capital expenditures:


		THREE MONTHS ENDED				NINE MONTHS ENDED					THREE MONTHS ENDED				SIX MONTHS ENDED
		SEPTEMBER 30				SEPTEMBER 30					JUNE 30				JUNE 30
		2020		2019		2020		2019			2021		2020		2021		2020
Revenues	Revenues									Revenues
Coal Mining	Coal Mining	$	20,395	$	18,799	$	62,896	$	58,119	Coal Mining	$	23,063	$	21,573	$	46,802	$	42,501
NAMining	NAMining	9,443		8,993		33,115		30,496		NAMining	17,486		12,048		33,628		23,672
Minerals Management	Minerals Management	2,722		5,022		9,950		25,950		Minerals Management	5,608		1,987		11,108		7,228
Unallocated Items	Unallocated Items	904		52		1,257		726		Unallocated Items	910		327		1,053		353
Eliminations	Eliminations	(1,169)		(263)		(1,924)		(1,239)		Eliminations	(1,171)		(580)		(1,590)		(755)
Total	Total	$	32,295	$	32,603	$	105,294	$	114,052	Total	$	45,896	$	35,355	$	91,001	$	72,999

Operating profit (loss)	Operating profit (loss)									Operating profit (loss)
Coal Mining	Coal Mining	$	11,174	$	10,492	$	25,857	$	27,761	Coal Mining	$	8,542	$	7,498	$	17,226	$	14,683
NAMining	NAMining	244		(358)		1,519		(743)		NAMining	783		544		913		1,275
Minerals Management	Minerals Management	1,673		3,900		6,450		22,358		Minerals Management	4,173		510		8,408		4,777
Unallocated Items	Unallocated Items	(3,623)		(5,470)		(12,341)		(15,336)		Unallocated Items	(4,795)		(4,158)		(9,568)		(8,718)
Eliminations	Eliminations	(70)		99		(25)		157		Eliminations	(33)		88		21		45
Total	Total	$	9,398	$	8,663	$	21,460	$	34,197	Total	$	8,670	$	4,482	$	17,000	$	12,062

~~Table of Contents~~

Expenditures for property, plant and equipment
Coal Mining $ 3,150 $ 2,291 $ 7,817 $ 6,542
NAMining 3,220 4,971 10,406 6,213
Minerals Management 633 0 1,372 291
Unallocated Items 0 35 207 218
Total $ 7,003 $ 7,297 $ 19,802 $ 13,264
Depreciation, depletion and amortization
Coal Mining $ 3,793 $ 3,102 $ 10,951 $ 9,252
NAMining 723 588 2,021 1,699
Minerals Management 327 324 981 1,057
Unallocated Items 33 30 91 87
Total $ 4,876 $ 4,044 $ 14,044 $ 12,095

~~NOTE 10—Income Taxes~~

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 quarterly income tax provision is generally comprised of tax expense on income or a benefit on a loss at the most recent estimated annual effective income tax rate, adjusted for the effect of discrete items.

The Company recorded income tax expense of $1.9 million for the three months ended September 30, 2020, or 18.8%, on income before income tax of $9.9 million, compared to income tax expense of $1.4 million, or 11.7%, on income before income tax of $11.6 million for the three months ended September 30, 2019. The three months ended September 30, 2020 include $4.2 million of discrete tax charges primarily related to settlement of tax examinations and changes in uncertain tax positions partially offset by a discrete tax benefit of $2.2 million, primarily due to return to provision adjustments. Discrete tax items in the three months ended September 30, 2019 were not material.

The Company recorded income tax expense of $1.3 million for the nine months ended September 30, 2020, or 6.1%, on income before income tax of $21.6 million, compared to income tax expense of $5.5 million, or 14.1%, on income before income tax of $38.7 million for the nine months ended September 30, 2019. The nine months ended September 30, 2020 include $4.2 million of discrete tax charges primarily related to settlement of tax examinations and changes in uncertain tax positions partially offset by a benefit of $1.8 million, primarily due to return to provision adjustments. Discrete tax items in the nine months ended September 30, 2019 were not material.

The return to provision adjustments recognized in 2020 include the utilization of the net operating loss carry back provisions allowed under the Coronavirus Aid, Relief, and Economic Security Act ("CARES Act") enacted in response to the COVID-19 pandemic. The CARES Act contains numerous income tax provisions, including among other items, temporary changes regarding the utilization of net operating losses. The CARES Act allows net operating tax losses incurred in 2018, 2019, and 2020 to be carried back to each of the five preceding taxable years to generate a refund of previously paid income taxes.

The Company’s estimated annual effective income tax rate, excluding discrete items, was (5.2%) and 14.0% for the nine months ended September 30, 2020 and 2019, respectively. The estimated annual effective income tax rate differs from the U.S. federal statutory rate due to the benefit from percentage depletion and in 2020 includes the benefit of utilizing the forecasted current year net operating tax loss that would otherwise be deductible at the current 21% statutory rate to offset taxable income in years that were taxed at a 35% rate. The Company expects to generate a net operating tax loss in 2020 primarily due to the realization of certain deferred tax assets.

~~NOTE 11—Asset Retirement Obligations~~

The Company’s obligations associated with the retirement of long-lived assets are recognized at fair value at the time the legal obligations are incurred. Upon initial recognition of a liability, a corresponding amount is capitalized as part of the carrying value of the related long-lived asset and is depreciated either by the straight-line method or the units-of-production method. The liability is accreted each period until the liability is settled or the asset is sold, at which time the liability is removed. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

~~Table of Contents~~

The Company's asset retirement obligations are principally for costs to close its surface mines and reclaim the land it has disturbed as a result of its normal mining activities as well as for costs to dismantle certain mining equipment at the end of the life of the mine. Management’s estimate involves a high degree of subjectivity. In particular, the obligation’s fair value is determined using a discounted cash flow technique and is based upon mining permit requirements and various assumptions including credit adjusted risk-free-rates, estimates of disturbed acreage, life of the mine, reclamation costs, the application of various environmental laws and regulation and assumptions regarding equipment productivity. The Company reviews its asset retirement obligations at each mine site at least annually and makes necessary adjustments for permit changes and for revisions of estimates of the timing and extent of reclamation activities and cost estimates.

The accretion of the liability is being recognized over the estimated life of each individual asset retirement obligation and is recorded in the line “Cost of sales” in the accompanying Unaudited Condensed Consolidated Statements of Operations. The associated asset is recorded in “Property, Plant and Equipment, net” in the accompanying Unaudited Condensed Consolidated Balance Sheets. The depreciation of the asset is recorded in the line “Cost of sales” in the accompanying Unaudited Condensed Consolidated Statements of Operations.

~~A reconciliation of the Company's beginning and ending aggregate carrying amount of the asset retirement obligations is as follows:~~

Coal Mining NAMining Unallocated Items NACCO
Consolidated
Balance at December 31, 2019 $ 19,015 $ 604 $ 17,240 $ 36,859
Liabilities incurred during the period 9,809 0 0 9,809
Liabilities settled during the period (5,957) 0 (562) (6,519)
Accretion expense 1,296 28 1,023 2,347
Revision of estimated cash flows 600 0 0 600
Balance at September 30, 2020 $ 24,763 $ 632 $ 17,701 $ 43,096

Asset retirement obligations are incurred at the time development of a new mine or mine area commences. During the third quarter of 2020, MLMC began development of a new mine area and as such, recorded an additional $9.8 million asset retirement obligation and a corresponding $9.8 million asset was capitalized as a component of Property, plant and equipment, net. The asset retirement obligation’s fair value was determined using a discounted cash flow technique and is based upon permit requirements and various estimates and assumptions that would be used by market participants, including estimates of disturbed acreage, reclamation costs and assumptions regarding equipment productivity.

During the third quarter of 2020, the Company transferred the mine permits for certain Centennial mines to an unrelated third party. As of September 30, 2020, the Company has $10.7 million of surety bonds outstanding related to the mines associated with the transferred mine permits. The third party that acquired the mine permits is required as part of the transaction to transfer or replace $4.9 million of the Company's outstanding surety bonds during the fourth quarter of 2020 and transfer or replace the remaining $5.8 million of outstanding surety bonds as soon thereafter as it is able.

If there is a claim under these surety bonds prior to the transfer or replacement of such bonds, the Company would be responsible to the surety company for any amounts it pays with respect to such claim, up to the amount of the outstanding surety bonds. As a result of the transfer of the mine permits, the Company was relieved of the associated mine reclamation obligations and therefore recorded a $4.8 million reduction to Centennial's asset retirement obligation, included in "Liabilities settled during the period" in the table above. In addition, as part of the transfer of the mine permits, the Company paid $1.9 million of cash, recorded $1.4 million in Other current assets for amounts owed to Centennial from the third-party acquirer, and recognized $1.9 million in Accounts payable and $2.4 million in Other long-term liabilities in the Unaudited Condensed Consolidated Balance Sheets. The liabilities are associated with amounts due to the third-party acquirer upon transfer or replacement of the surety bonds and a liability for the guarantee to stand ready to perform in the event there is a claim under the surety bonds. No payments have been required since the inception of these guarantees.

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. These legacy liabilities include obligations for water treatment and other environmental remediation that arose as part of the normal course of closing these underground mining operations. The accretion of the liability is recognized over the estimated life of the asset retirement obligation and is recorded in the line “Closed mine obligations” in the accompanying Unaudited Condensed Consolidated Statements of Operations. Since Bellaire's properties are no longer active operations, no associated asset has been capitalized.

~~Table of Contents~~

The fair value of Bellaire's Mine Water Treatment assets, which are recognized as a component of Other non-current assets on the Unaudited Condensed Consolidated Balance Sheets, are $10.3 million and $10.1 million at September 30, 2020 and December 31, 2019, respectively, and are legally restricted for purposes of settling the Bellaire asset retirement obligation. See Note 6 for further discussion of the Mine Water Treatment Trust.


Expenditures for property, plant and equipment and acquisition of mineral interests
Coal Mining	$	3,115	$	3,844	$	4,732	$	4,667
NAMining	2,952		3,163		5,818		7,186
Minerals Management	5,105		276		5,498		739
Unallocated Items	79		158		79		207
Total	$	11,251	$	7,441	$	16,127	$	12,799

Depreciation, depletion and amortization
Coal Mining	$	4,127	$	3,615	$	8,334	$	7,158
NAMining	930		652		1,829		1,298
Minerals Management	522		327		969		654
Unallocated Items	38		30		70		58
Total	$	5,617	$	4,624	$	11,202	$	9,168

1815

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

(~~Dollars~~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 ~~is the public holding company for The North American Coal Corporation~~®~~. The North American Coal Corporation and its affiliated companies (collectively, “NACoal”) operate in the mining and~~brings natural resources ~~industries~~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 ~~operating~~business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines ~~under long-term contracts with~~for power generation companies and an activated carbon ~~producer pursuant to a service-based business model.~~producer. The NAMining segment ~~provides value-added contract~~is a trusted mining ~~and other services~~partner for producers of aggregates, lithium and other minerals. The Minerals Management segment promotes the development of ~~the Company’s gas, oil~~mineral interests. In addition, Mitigation Resources of North America® (“Mitigation Resources”) provides stream and ~~coal reserves, generating income primarily from royalty-based lease payments from third parties.~~wetland mitigation solutions.

The Company ~~also~~ has ~~unallocated~~ items not directly attributable to a reportable segment ~~which~~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 ~~the Company’s mitigation banking business,~~ Mitigation Resources ~~of North America~~® ~~(“MRNA”),~~ and Bellaire Corporation ~~(“Bellaire”~~("Bellaire.")~~. MRNA 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 provision for income taxes and net income) are presented and discussed within this Form 10-Q on a consolidated basis.

The Company has continued to operate as an essential business during the COVID-19 pandemic because it supports critical infrastructure industries. The Company has procedures to limit the exposure of employees to the spread of COVID-19. The extent to which COVID-19 impacts the Company going forward will depend on numerous factors and future developments that remain uncertain.

~~The~~ Company’s operating segments are further described below:

Coal Mining Segment

On September 30, 2020, Caddo Creek’s customer, a division of Cabot Corporation, entered into a long-term supply agreement with a subsidiary of Advanced Emissions Solutions (“AES”) as well as an agreement for the sale of the Marshall Mine, operated by Caddo Creek, to a subsidiary of AES. AES announced its intent to close the Marshall Mine. Caddo Creek entered into a contract with a subsidiary of AES to perform the required mine reclamation. In 2019, total tons delivered by the Coal Mining segment was 34.6 million tons, of which 0.2 million tons related to Caddo Creek.

~~Table of Contents~~

All production from the Sabine Mine is delivered to Southwestern Electric Power Company's Henry W. Pirkey Plant. The Pirkey power plant has been dispatched at a lower rate during the first nine months of 2020 compared with the first nine months of 2019, resulting in a 43% reduction in tons delivered in 2020 compared with 2019. During the third quarter of 2020, Sabine’s customer reduced its expected future annual deliveries to be between 1.4 million and 1.7 million tons of lignite coal. Sabine historically has delivered between 2.5 million and 3.5 million tons of lignite coal annually, including 2.6 million tons in 2019 and 3.8 million tons in 2018.

The contract mining agreement between Camino Real Fuels, LLC (“Camino Real”) and its customer, Dos Republicas Coal Partnership (“DRCP”), terminated effective July 1, 2020 as a result of the unexpected termination by Comisión Federal de Electricidad (“CFE”) of its coal supply contract with an affiliate of DRCP. The termination of the contract between CFE and DRCP eliminated DRCP’s need for coal from Camino Real's Eagle Pass Mine, and resulted in mine closure. Mine reclamation is the responsibility of DRCP. Camino Real has no legal obligation to perform mine reclamation.

~~On May 7, 2020, Great River Energy ("GRE"),~~ Falkirk Mine's customer, and the Company's second largest customer, announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and modify the Spiritwood Station power plant to be fueled by natural gas. As noted in the announcement, GRE is willing to consider opportunities to sell Coal Creek Station. NACCO is actively engaged in the exploration of options that could, if successful, allow for transfer of ownership of the power plant to one or more third parties, which would preserve jobs at both Coal Creek Station andoperates the Falkirk ~~Mine. The Company believes Coal Creek Station is an efficient, economic and attractive generation and capacity asset, and its continued long-term operation is~~Mine in ~~the best interests of the employees and the local community.~~

North Dakota. Falkirk ~~Mine~~ is the sole supplier of lignite coal to the Coal Creek Station power plant pursuant to a ~~long-term~~ contract under which Falkirk also supplies approximately 0.3 million tons of lignite coal per year to Spiritwood ~~Station. Falkirk has approximately 480 employees,~~Station power plant. Coal Creek Station and Spiritwood Station are owned by Great River Energy (“GRE”). In May 2020, GRE announced its intent to sell or retire Coal Creek Station in ~~2019, delivered a total~~the second half of ~~7.4 million tons~~2022 and modify Spiritwood Station to be fueled by natural gas.

On June 30, 2021, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct current transmission line to Bismarck, North Dakota-based Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. The transaction between GRE and Rainbow Energy is subject to the satisfaction of ~~lignite coal and contributed approximately $16 million to NACCO’s Earnings from Unconsolidated Operations. The closure~~certain conditions, including regulatory approvals associated with the sale of Coal Creek Station ~~would~~and the related transmission assets and the posting of a performance bond related to final mine reclamation. If the conditions are satisfied, the transaction is expected to close before the end of 2021.

Upon completion of the sale of Coal Creek Station, the existing Coal Sales Agreement, the existing Mortgage and Security Agreement and the existing Option Agreement between GRE and Falkirk will be terminated. Falkirk and GRE have entered into a ~~material adverse effect on~~termination and release of claims agreement. Upon completion of the ~~long-term earnings~~sale of ~~NACCO.~~Coal Creek Station, GRE will pay Falkirk $14.0 million in cash, as well as transfer ownership of an office building located in Bismarck, North Dakota, and convey membership units in Midwest AgEnergy to NACoal. NACCO currently holds a $5.0 million investment in Midwest AgEnergy, which operates two ethanol facilities in North Dakota.

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If GRE's efforts to sell the power plant are successful, a new Coal Sales Agreement (“CSA”) between Falkirk and Rainbow Energy will become effective and Falkirk will begin supplying all coal requirements of Coal Creek Station concurrent with Rainbow Energy’s acquisition of the power plant. Falkirk will no longer make any coal deliveries to GRE’s Spiritwood Station. Falkirk will be paid a management fee and Rainbow Energy will be responsible for funding all mine operating costs and directly or indirectly providing all of the capital required to operate the mine. The CSA specifies that Falkirk will perform final mine reclamation, which will be funded in its entirety by Rainbow Energy. 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. If Rainbow Energy terminates the CSA and closes Coal Creek Station before 2027, Falkirk will be entitled to an additional payment from GRE under the terms of the termination and release of claims agreement. The additional payment amount ranges from $8 million if the closure occurs before 2024 to $2 million if the closure occurs in 2026. 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 current fee levels, and thereafter adjusts annually according to specific indices which track broad measures of U.S. inflation.

Bisti supplies the Four Corners Power Plant through its contract ~~between~~mining agreement with the Navajo Transitional Energy Company ("NTEC"). On June 17, 2021, the Company received notification that the contract mining agreement between Bisti and ~~GRE specify that GRE~~NTEC will be terminated effective September 30, 2021. As required under the agreement, it is ~~responsible~~anticipated NTEC will pay NACCO a termination fee of approximately $10 million. NTEC will assume control and responsibility for ~~all costs related to mine closure,~~operation of the Navajo Mine upon termination of the contract mining agreement. All liabilities, including ~~but not limited to, final~~ mine reclamation, ~~costs, post-retirement medical benefits~~are the responsibility of NTEC.

Sabine operates the Sabine Mine in Texas. All production from Sabine is delivered to Southwestern Electric Power Company's (“SWEPCO”) Henry W. Pirkey Plant (the “Pirkey Plant”). SWEPCO is an American Electric Power (“AEP”) company. In November 2020, AEP announced it intends to retire the Pirkey Plant in 2023. SWEPCO expects deliveries from Sabine to continue until the first quarter of 2023 at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the responsibility of SWEPCO.

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 ~~pension costs~~Leland Olds Station. The Synfuels Plant is a coal gasification plant that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. In November 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 beginning in 2026. Basin Electric indicated that if it decides to proceed with ~~respect~~any changes that could reduce or eliminate the use of coal, the feedstock change is not expected to ~~Falkirk employees.~~occur before 2026. In June 2021, Basin Electric announced it was also evaluating the Synfuels Plant for possible sale.

Coteau, Coyote, Falkirk, MLMC and Sabine supply lignite coal for power generation. Bisti supplies sub-bituminous coal for power generation. Demery supplies lignite coal for the production of activated carbon. Each mine is the exclusive supplier of coal to its customers' facilities. Each of these mines deliver their coal production to adjacent or nearby power plants, synfuels plants or an activated carbon processing facility under long-term supply contracts. ~~Each operating mine is the exclusive supplier of~~MLMC’s coal supply contract contains a take or pay provision; all other coal supply contracts are requirements contracts under which earnings can fluctuate. In addition, certain coal supply contracts can be terminated early, which would result in a reduction to ~~its customers' facilities.~~future earnings.

All operating coal mines other than MLMC 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 ~~VIE's~~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 expense line on the

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Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. ~~All of~~See Note 6 for further information on the Unconsolidated ~~Subsidiaries are accounted for under the equity method. See Note 7 for further discussion.~~

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~~beginning in the fourth quarter of 2020. The consolidation of these entities will not materially change the Company’s Unaudited Condensed Consolidated Balance Sheet.~~Subsidiaries.

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, the persistence of low diesel fuel prices can negatively affect 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.

~~As of September 30, 2020, all of the Liberty Fuels Company, LLC mine areas have been reclaimed and final mine reclamation activities, primarily monitoring, will continue until final bond release.~~

~~Centennial Natural Resources (“Centennial”), located in Alabama, ceased coal production at the end of 2015.~~

The coal reserves at Coteau, Falkirk, Coyote, MLMC and Centennial Natural Resources ("Centennial") are owned or controlled by the Company. The coal reserves at all other mines are owned or controlled by the respective mine’s customer.

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 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.

Caddo Creek Resources Company, LLC (“Caddo Creek”) ceased all mining and delivery of lignite and commenced mine reclamation during 2020. The ~~contracts under which certain~~reclamation at Caddo Creek is expected to be substantially complete by June 30, 2022. The terms of the ~~Unconsolidated Subsidiaries operate provide that, under certain conditions, including default,~~contract to perform mine reclamation contain a fixed-price component and therefore, Caddo Creek no longer meets the ~~customer(s) involved may elect or be obligated to acquire~~VIE criteria. As a result, Caddo Creek is consolidated within the assets (subject to the liabilities) or the capital stock of the Coal Mining subsidiary for an amount effectively equal to book value. The Company does not know of any conditions of default that currently exist.Company's financial statements.

NAMining Segment

Minerals Management Segment

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The Company’s ~~gas, oil~~legacy royalty and ~~undeveloped coal reserves~~mineral interests are located in Ohio (Utica and Marcellus shale natural gas), Louisiana (Haynesville shale and Cotton Valley formation natural gas), Texas ~~(Permian basin oil~~(Cotton Valley and Austin Chalk formation natural gas), Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal, ~~and~~ coalbed methane and natural gas) and North Dakota ~~(coal)~~(coal, oil and natural gas).

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The majority of the Company’s ~~existing~~legacy reserves were acquired as part of its historical coal mining operations.

The Minerals Management segment ~~derives income primarily by entering into contracts with third-party operators, granting them~~owns royalty interests, mineral interests, nonparticipating royalty interests, and overriding royalty interests ("ORRI"). The Company may own more than one type of mineral and royalty interest in the ~~rights to explore, produce and sell natural resources~~same tract of land. For example, where the Company owns an ORRI in ~~exchange for royalty payments based~~a lease on the ~~lessees' sales~~same tract of ~~natural gas and,~~land in which it owns a mineral interest, the ORRI in that tract will relate to ~~a lesser extent, oil and coal. Specialized employees~~the same gross acres as the mineral interest in ~~the~~that tract.

The Minerals Management segment ~~also provide surface~~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 have any investments under which it would be required to bear the cost of exploration, production or development.

As an owner of royalty and mineral ~~acquisition~~interests, the Company’s access to information concerning activity and ~~lease maintenance services related~~operations of its royalty and mineral interests is limited. The Company does not have information that would be available to ~~Company operations.~~a company with oil and natural gas operations because detailed information is not generally available to owners of royalty and mineral interests.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Refer to the discussion of the Company's Critical Accounting Policies and Estimates as disclosed on pages 3039 through 3241 in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020. The Company's Critical Accounting Policies and Estimates have not materially changed since December 31, ~~2019.~~2020.

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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
		2020			2019			2020			2019				2021			2020			2021			2020
Revenues:	Revenues:													Revenues:
Coal Mining	Coal Mining	$	20,395		$	18,799		$	62,896		$	58,119		Coal Mining	$	23,063		$	21,573		$	46,802		$	42,501
NAMining	NAMining	9,443			8,993			33,115			30,496			NAMining	17,486			12,048			33,628			23,672
Minerals Management	Minerals Management	2,722			5,022			9,950			25,950			Minerals Management	5,608			1,987			11,108			7,228
Unallocated Items	Unallocated Items	904			52			1,257			726			Unallocated Items	910			327			1,053			353
Eliminations	Eliminations	(1,169)			(263)			(1,924)			(1,239)			Eliminations	(1,171)			(580)			(1,590)			(755)
Total revenue	Total revenue	$	32,295		$	32,603		$	105,294		$	114,052		Total revenue	$	45,896		$	35,355		$	91,001		$	72,999
Operating profit (loss):	Operating profit (loss):													Operating profit (loss):
Coal Mining	Coal Mining	$	11,174		$	10,492		$	25,857		$	27,761		Coal Mining	$	8,542		$	7,498		$	17,226		$	14,683
NAMining	NAMining	244			(358)			1,519			(743)			NAMining	783			544			913			1,275
Minerals Management	Minerals Management	1,673			3,900			6,450			22,358			Minerals Management	4,173			510			8,408			4,777
Unallocated Items	Unallocated Items	(3,623)			(5,470)			(12,341)			(15,336)			Unallocated Items	(4,795)			(4,158)			(9,568)			(8,718)
Eliminations	Eliminations	(70)			99			(25)			157			Eliminations	(33)			88			21			45
Total operating profit	Total operating profit	$	9,398		$	8,663		$	21,460		$	34,197		Total operating profit	$	8,670		$	4,482		$	17,000		$	12,062
Interest expense	Interest expense	336			230			1,069			683			Interest expense	359			330			715			733
Interest income	Interest income	(95)			(1,878)			(625)			(3,012)			Interest income	(100)			(129)			(220)			(530)
Income from other unconsolidated affiliates		(18)			(327)			(230)			(972)
Closed mine obligations	Closed mine obligations	395			383			1,219			1,079			Closed mine obligations	364			390			747			824
Gain on equity securities	Gain on equity securities	(35)			(108)			(351)			(1,067)			Gain on equity securities	(1,262)			(1,512)			(2,085)			(316)
Other, net	Other, net	(1,064)			(1,258)			(1,181)			(1,236)			Other, net	(127)			(181)			(257)			(329)
Other (income) expense, net	Other (income) expense, net	(481)			(2,958)			(99)			(4,525)			Other (income) expense, net	(766)			(1,102)			(1,100)			382
Income before income tax provision		9,879			11,621			21,559			38,722
Income tax provision		1,857			1,357			1,321			5,465
Income before income tax provision (benefit)														Income before income tax provision (benefit)	9,436			5,584			18,100			11,680
Income tax provision (benefit)														Income tax provision (benefit)	2,931			(466)			2,634			(536)
Net income	Net income	$	8,022		$	10,264		$	20,238		$	33,257		Net income	$	6,505		$	6,050		$	15,466		$	12,216

Effective income tax rate	Effective income tax rate	18.8		%	11.7		%	6.1		%	14.1		%	Effective income tax rate	31.1		%	(8.3)		%	14.6		%	(4.6)		%

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

~~Table~~Second Quarter of ~~Contents~~

~~Third~~2021 Compared with Second Quarter of 2020, and First Six Months of 2021 Compared with ~~Third Quarter of 2019 and~~ First ~~Nine~~Six Months of 2020 ~~Compared with First Nine Months of 2019~~

Other (income) expense, net

North American Coal Corporation India Private Limited ("NACC India") was formed to provide technical business advisory services to the third-party owner of a coal mine in India. During 2014, NACC India's customer defaulted on its contractual payment obligations and as a result of this default, NACC India terminated its contract with the customer and began pursuing contractual remedies. During the third quarter of 2019, the Company received payment of $2.7Interest income decreased by $0.3 million from NACC India's customer, of which $1.4 million related to past invoices and has been reported on the line Other, net, and $1.3 million represented interest income and has been reported on the line Interest income. During the third quarter of 2020, the Company received an additional payment of $1.0 million from NACC India's customer which has been reported on the line, Other, net. Both of these lines are in the ~~Other (income) expense section of the Unaudited Condensed Consolidated Statements of Operations. The Company does not expect to receive any additional payments from NACC India’s customer.~~

~~Interest expense increased in the third quarter and the~~ first ~~nine~~six months of ~~2020~~2021 compared with the ~~2019 periods by $0.1 million and $0.4 million, respectively, due to higher average borrowings.~~

~~Interest income decreased in the third quarter and the first nine months of~~respective 2020 ~~compared with the 2019 periods by $1.8 million and $2.4 million, respectively,~~period primarily due to ~~the interest income related to the NACC India customer payment the Company received in 2019 and~~ lower interest rates ~~despite~~and a ~~higher~~lower average invested cash balance.

Income from other unconsolidated affiliates represents the financial results of NoDak. NoDak operated and maintained a coal drying system at a customer’s power plant. The NoDak contract expired on January 31, 2020, resulting in decreases of $0.3 million and $0.7 million, respectively, in Income from other unconsolidated affiliates during the third quarter and the first nine months of 2020 compared with the 2019 periods. Income from NoDak was $1.3 million for the year ended December 31, 2019.

Gain on equity securities represents changes in the market price of invested assets reported at fair value. The change in the ~~gains during the third~~second quarter of 2021 and the first ~~nine~~six months of ~~2020~~2021 compared with the ~~gains during the 2019~~respective 2020 periods was due to ~~lower returns on invested~~fluctuations in the market prices of the underlying assets. See Note 65 to the Unaudited Condensed Consolidated Financial Statements for further discussion of equity securities.

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Income Taxes

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. Changes in the estimated annual effective tax rate result in a cumulative adjustment. The ~~quarterly income tax provision is generally comprised of tax expense on income or a benefit on a loss at~~increase in the ~~most recent~~ estimated annual effective income tax rate ~~adjusted~~ for the ~~effect of discrete items.~~

~~The Company recorded income tax expense of $1.9 million for the three months~~quarter ended ~~September~~June 30, ~~2020, or 18.8%, on income before income tax of $9.9 million,~~2021 compared to the quarter ended March 31, 2021 reflects the impact of higher pre-tax income, ~~tax expense of $1.4 million, or 11.7%, on income before income tax of $11.6 million for~~including the ~~three months ended September 30, 2019. The three months ended September 30, 2020 include $4.2 million of discrete tax charges primarily related to~~anticipated settlement of tax examinations and changes in uncertain tax positions partially offset by a discrete tax benefit of $2.2 million, primarily due to return to provision adjustments. Discrete tax items in the three months ended September 30, 2019 were not material.

~~The return to provision adjustments recognized in 2020 include the utilization of the net operating loss carry back provisions allowed~~ under the ~~Coronavirus Aid, Relief,~~termination and ~~Economic Security Act ("CARES Act") enacted in response to~~release of claims agreement with GRE and the ~~COVID-19 pandemic. The CARES Act contains numerous income tax provisions, including among other items, temporary changes~~

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~~regarding~~termination fee associated with the utilization of net operating losses. The CARES Act allows net operating tax losses incurred in 2018, 2019, and 2020 to be carried back to each of the five preceding taxable years to generate a refund of previously paid income taxes.

Bisti contract termination.

~~The Company’s estimated annual effective income tax rate, excluding discrete items, was (5.2%) and 14.0% for the nine months ended September 30, 2020 and 2019, respectively.~~ The estimated annual effective income tax rate differs from the U.S. federal statutory rate due to the benefit from percentage ~~depletion~~depletion. The quarterly income tax provision is generally comprised of tax expense on income or a benefit on a loss at the most recent estimated annual effective income tax rate, adjusted for the effect of discrete items.

The enactment of tax reform legislation could adversely impact the Company’s financial position and results of operations. Legislation or other changes in ~~2020 includes~~U.S. tax law could increase the ~~benefit of utilizing~~Company’s tax liability and adversely affect its after-tax profitability. The Biden administration has proposed to increase the ~~forecasted current year net operating~~U.S. corporate income tax ~~loss that would otherwise be deductible at the current 21% statutory~~ rate to ~~offset taxable~~28% from 21% and eliminate certain U.S. federal income tax benefits currently available to coal mining and oil and gas exploration and development companies. Such proposed changes could have a significant impact on the Company’s effective income tax rate, cash tax expenses and deferred taxes in ~~years that were taxed at a 35% rate. The Company expects to generate a net operating tax loss in 2020 primarily due to the realization of certain deferred tax assets.~~future periods.

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:


		2020		2019		Change			2021		2020		Change
Operating activities:	Operating activities:							Operating activities:

Net cash provided by operating activities		$	2,760	$	47,264	$	(44,504)
Net cash provided by (used for) operating activities								Net cash provided by (used for) operating activities	$	29,318	$	(12,489)	$	41,807

Investing activities:	Investing activities:							Investing activities:
Expenditures for property, plant and equipment		(19,802)		(13,264)		(6,538)
Expenditures for property, plant and equipment and acquisition of mineral interests								Expenditures for property, plant and equipment and acquisition of mineral interests	(16,127)		(12,799)		(3,328)
Other	Other	(1,378)		4,455		(5,833)		Other	38		(1,845)		1,883
Net cash used for investing activities	Net cash used for investing activities	(21,180)		(8,809)		(12,371)		Net cash used for investing activities	(16,089)		(14,644)		(1,445)
Cash flow before financing activities	Cash flow before financing activities	$	(18,420)	$	38,455	$	(56,875)	Cash flow before financing activities	$	13,229	$	(27,133)	$	40,362

The ~~$44.5~~$41.8 million ~~decrease~~change in net cash provided by (used for) operating activities was primarily due to a net favorable change in working capital, ~~changes,~~ including:

•~~Increased~~Decreased payments made under deferred compensation and long-term incentive compensation plans ~~during~~in the first ~~nine~~six months of ~~2020~~2021 compared with the first ~~nine~~six months of ~~2019.~~

•~~An increase in Refundable income taxes related to the carry back of net operating tax loss claims under the CARES Act during the first nine months of 2020.~~2020, and

•A ~~smaller decrease~~reduction in ~~Accounts receivables during the first nine months of 2020 compared to the decrease during the first nine months of 2019. The large decrease~~refundable federal income taxes in the first ~~nine~~six months of ~~2019 was primarily due to the timing of sales at MLMC.~~

•An2021 compared with an increase in ~~Other current assets due to~~ the ~~recognition~~first six months of ~~a $2.3 million note receivable in settlement of DRCP's outstanding receivable balance associated with the closure of Camino Real's Eagle Pass Mine during 2020 and a change in prepaid expenses.~~2020.

The change in net cash used for investing activities was primarily attributable to an increase in ~~expenditures for property, plant and equipment at~~ the ~~NAMining and Coal Mining segments.~~acquisition of mineral interests within the Minerals Management segment.


		2020		2019		Change			2021		2020		Change
Financing activities:	Financing activities:							Financing activities:
Net reductions to long-term debt and revolving credit agreement		$	(1,858)	$	(3,433)	$	1,575
Net (reductions) additions to long-term debt and revolving credit agreement								Net (reductions) additions to long-term debt and revolving credit agreement	$	(13,881)	$	3,479	$	(17,360)
Cash dividends paid	Cash dividends paid	(4,045)		(3,808)		(237)		Cash dividends paid	(2,786)		(2,690)		(96)
Purchase of treasury shares	Purchase of treasury shares	(1,002)		(1,410)		408		Purchase of treasury shares	—		(1,002)		1,002

Net cash used for financing activities	Net cash used for financing activities	$	(6,905)	$	(8,651)	$	1,746	Net cash used for financing activities	$	(16,667)	$	(213)	$	(16,454)

The change in net cash used for financing activities was primarily due to ~~fewer~~ repayments during the first ~~nine~~six months of ~~2020~~2021 compared with borrowings during the first ~~nine~~six months of ~~2019.~~

2020.

2421

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Financing Activities

Financing arrangements are obtained and maintained at the NACoal level. NACCO has not guaranteed any borrowings of NACoal. The borrowing agreements at NACoal allow for the payment to NACCO of dividends and advances under certain circumstances. Dividends (to the extent permitted by NACoal's borrowing agreement) and management fees are the primary sources of cash for NACCO and enable the Company to pay dividends to stockholders.

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.

NACoal has an unsecured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that expires in August 2022. Borrowings outstanding under the NACoal Facility were $9$19.0 million at ~~September~~June 30, ~~2020.~~2021. At ~~September~~June 30, ~~2020,~~2021, the excess availability under the NACoal Facility was ~~$138.0~~$109.9 million, which reflects a reduction for outstanding letters of credit of ~~$3.0~~$21.1 million.

The NACoal Facility has performance-based pricing, which sets interest rates based upon NACoal 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, ~~2020,~~2021, for base rate and LIBOR loans were 1.00% and 2.00%, 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% on the unused commitment at ~~September~~June 30, ~~2020.~~2021. The weighted average interest rate applicable to the NACoal Facility at ~~September~~June 30, ~~2020~~2021 was ~~2.11%~~2.10% including the floating rate margin.

The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum debt to EBITDA ratio of 3.00 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 EBITDA ratio of 2.00 to 1.00, or if greater than 2.00 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, ~~2020,~~2021, NACoal was in compliance with all financial covenants in the NACoal Facility.

~~Capital~~ Surety Bonds

The Company uses surety bonds to guarantee performance of its consolidated mine reclamation obligations. During the six months ended June 30, 2021, the Company replaced $8.0 million of outstanding surety bonds with letters of credit. In addition, during the six months ended June 30, 2021, the Company provided a $10.0 million letter of credit to its surety company to collateralize a portion of its remaining surety bonds. The Company expects to provide another $10.0 million letter of credit to its surety company before the end of 2021. The use of letters of credit reduces the amount available under the NACoal Facility.

Expenditures for property, plant and equipment and mineral interests

Expenditures for property, plant and equipment and mineral interests were ~~$19.8~~$16.1 million during the first ~~nine~~six months of ~~2020.~~2021. Planned expenditures for the remainder of ~~2020~~2021 are expected to be approximately ~~$30~~$45 million, primarily consisting of ~~$12~~$21 million in the Coal Mining segment, $3$19 million in the NAMining segment and ~~$15~~$5 million in the Minerals Management segment.

In the Coal Mining segment, elevated levels of expected capital expenditures through 2021 are primarily related to spending at MLMC as it develops a new mine area. In the NAMining segment, expected capital expenditures in ~~2020~~2021 are primarily for the acquisition, relocation and refurbishment of ~~draglines.~~draglines and the acquisition of other mining equipment to support the expansion of contract mining services beyond NAMining's historical dragline-oriented model. In the Minerals Management segment, expected expenditures in ~~2020~~2021 are primarily for the acquisition of mineral and royalty interests.

Planned expenditures for 2021 are expected to be approximately $41 million, primarily consisting of $24 million in the Coal Mining segment, $7 million in the NAMining segment and $10 million in the Minerals Management segment.

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

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Capital Structure

NACCO's consolidated capital structure is presented below:


		SEPTEMBER 30 2020		DECEMBER 31 2019		Change			JUNE 30 2021		DECEMBER 31 2020		Change
Cash and cash equivalents	Cash and cash equivalents	$	97,567	$	122,892	$	(25,325)	Cash and cash equivalents	$	85,012	$	88,450	$	(3,438)
Other net tangible assets	Other net tangible assets	217,354		174,465		42,889		Other net tangible assets	250,816		244,907		5,909
Intangible assets, net	Intangible assets, net	35,599		37,902		(2,303)		Intangible assets, net	33,437		35,330		(1,893)
Net assets	Net assets	350,520		335,259		15,261		Net assets	369,265		368,687		578
Total debt	Total debt	(23,142)		(24,943)		1,801		Total debt	(31,973)		(46,465)		14,492
Bellaire closed mine obligations	Bellaire closed mine obligations	(20,889)		(20,924)		35		Bellaire closed mine obligations	(21,565)		(21,598)		33
Total equity	Total equity	$	306,489	$	289,392	$	17,097	Total equity	$	315,727	$	300,624	$	15,103
Debt to total capitalization	Debt to total capitalization	7%		8%		(1)%		Debt to total capitalization	9%		13%		(4)%

The increase in other net tangible assets was primarily due to ~~increases~~an increase in ~~Property, plant~~prepaid insurance from higher insurance premiums and ~~equipment as well as payments made for deferred compensation and accrued incentive compensation~~a decrease in payroll obligations, partially offset by a decrease in refundable incomes taxes at ~~September~~June 30, ~~2020~~2021 compared with December 31, ~~2019.~~2020.

Contractual Obligations, Contingent Liabilities and Commitments

Since December 31, ~~2019,~~2020, 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 page 3646 in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020, except for the changes in the letters of credit as described under the Surety Bond section in this Form 10-Q. See Note 76 to the Unaudited Condensed Consolidated Financial Statements for a discussion of certain guarantees related to Coyote Creek.

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 30 (in millions):~~June 30:


		THREE MONTHS		NINE MONTHS			THREE MONTHS		SIX MONTHS
		2020	2019	2020	2019		2021	2020	2021	2020
Unconsolidated operations	Unconsolidated operations	7.6	8.7	21.2	24.2	Unconsolidated operations	6,076	5,947	13,663	13,628
Consolidated operations	Consolidated operations	0.7	0.7	2.3	2.2	Consolidated operations	775	815	1,610	1,582
Total tons delivered	Total tons delivered	8.3	9.4	23.5	26.4	Total tons delivered	6,851	6,762	15,273	15,210

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					THREE MONTHS				SIX MONTHS
		2020		2019		2020		2019			2021		2020		2021		2020
Revenues	Revenues	$	20,395	$	18,799	$	62,896	$	58,119	Revenues	$	23,063	$	21,573	$	46,802	$	42,501
Cost of sales	Cost of sales	16,379		16,383		57,514		53,561		Cost of sales	19,652		19,861		41,254		41,135
Gross profit	Gross profit	4,016		2,416		5,382		4,558		Gross profit	3,411		1,712		5,548		1,366
Earnings of unconsolidated operations(a)	Earnings of unconsolidated operations(a)	14,277		16,211		42,104		45,521		Earnings of unconsolidated operations(a)	12,392		12,800		26,796		27,827
Selling, general and administrative expenses	Selling, general and administrative expenses	6,385		7,502		19,326		20,187		Selling, general and administrative expenses	6,278		6,222		13,192		12,941
Amortization of intangible assets	Amortization of intangible assets	734		715		2,303		2,243		Amortization of intangible assets	911		792		1,893		1,569
Gain on sale of assets		—		(82)		—		(112)
Loss on sale of assets										Loss on sale of assets	72		—		33		—
Operating profit	Operating profit	$	11,174	$	10,492	$	25,857	$	27,761	Operating profit	$	8,542	$	7,498	$	17,226	$	14,683

(a) See Note 76 to the Unaudited Condensed Consolidated Financial Statements for a discussion of the Company's unconsolidated subsidiaries, including summarized financial information.

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~~Third~~Second Quarter of ~~2020~~2021 Compared with ~~Third~~Second Quarter of ~~2019~~2020

Revenues increased ~~8.5%~~6.9% in the ~~third~~second quarter of 2021 compared with the second quarter of 2020 ~~compared with the third quarter of 2019~~ primarily due to ~~an increase in reimbursable costs at MLMC. The sales price at MLMC is index-based and includes adjustments for coal quality and reimbursable costs.~~the recognition of reclamation revenue from Caddo Creek. During the fourth quarter of 2020, Caddo Creek entered into a contract with a subsidiary of Advanced Emissions Solutions to perform mine reclamation. As a result of these changes, Caddo Creek financial results are consolidated within the Coal Mining segment.

The following table identifies the components of change in operating profit for the ~~third~~second quarter of ~~2020~~2021 compared with the ~~third~~second quarter of ~~2019:~~2020:


		Operating Profit			Operating Profit
2019		$	10,492
2020				2020	$	7,498
Increase (decrease) from:	Increase (decrease) from:			Increase (decrease) from:
Gross profit	Gross profit	1,600		Gross profit	1,699
Earnings of unconsolidated operations				Earnings of unconsolidated operations	(408)
Amortization of intangibles				Amortization of intangibles	(119)
Loss on sale of assets				Loss on sale of assets	(72)
Selling, general and administrative expenses	Selling, general and administrative expenses	1,117		Selling, general and administrative expenses	(56)
Earnings of unconsolidated operations		(1,934)
Net gain on sale of assets		(82)
Amortization of intangibles		(19)
2020		$	11,174
2021				2021	$	8,542

Operating profit increased ~~$0.7~~$1.0 million in the ~~third~~second quarter of ~~2020~~2021 compared with the ~~third~~second quarter of ~~2019~~2020 primarily due to an increase in gross profit, ~~and a decrease in selling, general and administrative expenses,~~ partially offset by a decrease in earnings of unconsolidated operations. The improvement in gross profit was mainly due to ~~an increase~~a reduction in ~~the profit per ton delivered~~costs for outside services at ~~MLMC. The decrease in selling, general~~Centennial Natural Resources and ~~administrative expenses was primarily attributable to lower employee-related expenses.~~ income associated with mine reclamation at Caddo Creek.

The decrease in earnings of unconsolidated operations was ~~mainly~~primarily due to athe expected reduction in ~~tons delivered due to decreases in customer demand and~~fees earned at the Liberty Mine as the scope of final reclamation activities declined, the termination of the Camino Real Fuels, LLC contract mining agreement effective July 1, ~~2020. Camino Real delivered 0.3 million tons~~2020 and the cessation of coal deliveries at Caddo Creek. These decreases were partially offset by an increase in customer demand at Falkirk and Sabine.

Higher insurance expense was offset by a decrease in other selling, general and administrative expenses including employee-related costs resulting from lower headcount, primarily due to the 2020 voluntary separation program. A portion of the increase in insurance expense is passed through to the Unconsolidated Subsidiaries and included in Earnings of Unconsolidated Operations.

First Six Months of 2021 Compared with First Six Months of 2020

Revenues increased 10.1% in the first six months of ~~2020 and 1.6 million tons in full-year 2019.~~

~~First Nine Months of 2020 Compared with First Nine Months of 2019~~

~~Revenues increased 8.2% in the first nine months of 2020~~2021 compared with the first ~~nine~~six months of ~~2019~~2020 primarily due to ~~an increase in reimbursable costs and tons delivered at MLMC. The sales price at MLMC is index-based and includes adjustments for coal quality and reimbursable costs.~~the recognition of reclamation revenue from Caddo Creek.

The following table identifies the components of change in operating profit for the first ~~nine~~six months of ~~2020~~2021 compared with the first ~~nine~~six months of ~~2019:~~2020:


		Operating Profit			Operating Profit
2019		$	27,761
2020				2020	$	14,683
Increase (decrease) from:	Increase (decrease) from:			Increase (decrease) from:
Gross profit				Gross profit	4,182
Earnings of unconsolidated operations	Earnings of unconsolidated operations	(3,417)		Earnings of unconsolidated operations	(1,031)
Net gain on sale of assets		(112)
Amortization of intangibles	Amortization of intangibles	(60)		Amortization of intangibles	(324)
Selling, general and administrative expenses	Selling, general and administrative expenses	861		Selling, general and administrative expenses	(251)
Gross profit		824
2020		$	25,857
Loss on sale of assets				Loss on sale of assets	(33)
2021				2021	$	17,226

Operating profit ~~decreased $1.9~~increased $2.5 million in the first ~~nine~~six months of ~~2020~~2021 compared with the first ~~nine~~six months of ~~2019~~2020 primarily due to an increase in gross profit, partially offset by a decrease in earnings of unconsolidated ~~operations, partially offset by~~operations. The improvement in gross

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profit was mainly due to a ~~decrease~~reduction in ~~selling, general and administrative expenses~~the cost per ton and an overall increase in the profit per ton delivered at MLMC. In addition, a reduction in costs for outside services at Centennial Natural Resources and income associated with mine reclamation at Caddo Creek also contributed to the improvement in gross profit.

The decrease in earnings of unconsolidated operations was ~~mainly~~primarily due to athe expected reduction in ~~tons delivered, primarily~~fees earned at ~~Sabine,~~the Liberty Mine as the scope of final reclamation activities declined, the termination of the Camino Real ~~Coteau~~Fuels, LLC contract mining agreement effective July 1, 2020 and ~~Bisti,~~the cessation of coal deliveries at Caddo Creek. These decreases were partially offset by an increase in tons delivered at Coyote Creek. The power plants served by Sabine and Coteau were dispatched at lower rates during the first nine months of 2020 compared with the first nine months of 2019. The reduction in tons delivered at Camino Real was due to a decrease in customer demand ~~in the first six months of 2020~~at Falkirk and the termination of the Camino Real contract mining agreement effective July 1, 2020. The reduction in coal tons delivered at Bisti was due to an extended plant outage during the first nine months of 2020.Sabine.

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The ~~decrease~~increase in selling, general and administrative expenses was primarily ~~attributable~~due to ~~lower employee-related expenses~~higher insurance expense partially offset by ~~higher outside service fees. The improvement~~a decrease in ~~gross profit was~~employee-related costs resulting from lower headcount, primarily due to anthe 2020 voluntary separation program. A portion of the increase in insurance expense is passed through to the ~~profit per ton delivered at MLMC.~~Unconsolidated Subsidiaries and included in Earnings of Unconsolidated Operations.

NORTH AMERICAN MINING ("NAMining") SEGMENT

FINANCIAL REVIEW

Tons ~~of limestone~~ delivered by the NAMining segment were as follows for the three and ~~nine~~six months ended ~~September 30 (in millions):~~June 30:


		THREE MONTHS		NINE MONTHS			THREE MONTHS		SIX MONTHS
		2020	2019	2020	2019		2021	2020	2021	2020
Unconsolidated operations	Unconsolidated operations	2.4	1.7	6.8	6.1	Unconsolidated operations	2,675	2,227	4,867	4,482
Consolidated operations	Consolidated operations	9.2	8.5	28.1	27.6	Consolidated operations	10,836	8,607	21,242	18,886
Total tons delivered	Total tons delivered	11.6	10.2	34.9	33.7	Total tons delivered	13,511	10,834	26,109	23,368

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					THREE MONTHS				SIX MONTHS
		2020		2019		2020		2019			2021		2020		2021		2020
Revenues	Revenues	$	9,443	$	8,993	$	33,115	$	30,496	Revenues	$	17,486	$	12,048	$	33,628	$	23,672
Cost of sales	Cost of sales	8,808		9,407		30,797		29,880		Cost of sales	16,206		11,408		31,671		21,989
Gross profit (loss)		635		(414)		2,318		616
Gross profit										Gross profit	1,280		640		1,957		1,683
Earnings of unconsolidated operations(a)	Earnings of unconsolidated operations(a)	868		1,227		2,822		2,330		Earnings of unconsolidated operations(a)	1,150		978		2,088		1,954
Selling, general and administrative expenses	Selling, general and administrative expenses	1,259		1,183		3,868		3,708		Selling, general and administrative expenses	1,651		1,321		3,138		2,609
Gain on sale of assets	Gain on sale of assets	—		(12)		(247)		(19)		Gain on sale of assets	(4)		(247)		(6)		(247)
Operating profit (loss)		$	244	$	(358)	$	1,519	$	(743)
Operating profit										Operating profit	$	783	$	544	$	913	$	1,275

(a) See Note 76 to the Unaudited Condensed Consolidated Financial Statements for a discussion of the Company's unconsolidated subsidiaries, including summarized financial information.

~~Third Quarter of 2020 Compared with Third Quarter of 2019~~

Revenues increased ~~5.0%~~45.1% and 42.1% in the ~~third~~second quarter and first six months of ~~2020~~2021 compared with the ~~third quarter of 2019~~respective 2020 periods primarily due to an increase in reimbursable costs, which have an offsetting amount in cost of sales and have no impact on operating profit, and a substantial increase in tons ~~delivered~~delivered.

During the first quarter of 2021, NAMining entered into a 15-year mining services contract with a new customer at a limestone quarry in Central Florida. NAMining is operating a smaller dragline at this quarry while it relocates and ~~work related~~commissions a larger dragline that will increase production capacity. Deliveries are expected to be approximately 1.5 million tons annually once mining commences with the ~~Thacker Pass lithium project.~~larger dragline, which is anticipated to occur in 2023. NAMining also amended a contract during the first quarter of 2021 with an existing customer to operate an additional dragline at an existing limestone quarry in Florida. The relocation of these draglines is the main driver of the increase in reimbursable costs.

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The following table identifies the components of change in operating profit for the second quarter of 2021 compared with the second quarter of 2020:


	Operating Profit
2020	$	544
Increase (decrease) from:
Gross profit	640
Earnings of unconsolidated operations	172
Selling, general and administrative expenses	(330)
Net gain on sale of assets	(243)
2021	$	783

Operating profit increased $0.2 million in the second quarter of 2021 compared with the second quarter of 2020 primarily due to an increase in gross profit, partially offset by an increase in selling, general and administrative expenses. The improvement in gross profit was mainly due to favorable changes in the mix of customer requirements. The increase in selling, general and administrative expenses was primarily attributable to higher employee-related costs, including medical costs, and an increase in business development expenses.

The following table identifies the components of change in operating profit ~~(loss)~~ for the ~~third quarter~~first six months of ~~2020~~2021 compared with the ~~third quarter~~first six months of ~~2019:~~2020:


		Operating Profit (Loss)			Operating Profit
2019		$	(358)
2020				2020	$	1,275
Increase (decrease) from:	Increase (decrease) from:			Increase (decrease) from:
Selling, general and administrative expenses				Selling, general and administrative expenses	(529)
Net gain on sale of assets				Net gain on sale of assets	(241)
Gross profit	Gross profit	1,049		Gross profit	274
Earnings of unconsolidated operations	Earnings of unconsolidated operations	(359)		Earnings of unconsolidated operations	134
Selling, general and administrative expenses		(76)
Net gain on sale of assets		(12)
2020		$	244
2021				2021	$	913

Operating profit ~~increased $0.6~~decreased $0.4 million in the ~~third quarter~~first six months of ~~2020~~2021 compared with the ~~third quarter~~first six months of ~~2019~~2020 primarily due to an increase in ~~gross profit~~selling, general and administrative expenses, mainly attributable to higher employee-related costs and an increase in business development expenses, partially offset by ~~a decrease~~an improvement in ~~earnings of unconsolidated operations. Both variances are due to changes~~gross profit. The increase in ~~the mix of customer requirements.~~

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~~First Nine Months of 2020 Compared with First Nine Months of 2019~~

~~Revenues increased 8.6% in the first nine months of 2020 compared with the first nine months of 2019~~gross profit was primarily due to favorable changes in the mix of customer requirements, ~~and~~partially offset by a decrease in work related to the Thacker Pass lithium project.

~~The following table identifies the components of change in operating profit (loss) for the first nine months of 2020 compared with the first nine months of 2019:~~

Operating Profit (Loss)
2019 $ (743)
Increase (decrease) from:
Gross profit 1,702
Earnings of unconsolidated operations 492
Net gain on sale of assets 228
Selling, general and administrative expenses (160)
2020 $ 1,519

Operating profit increased $2.3 million in the first nine months of 2020 compared with the first nine months of 2019 primarily due to increases in gross profit and earnings of unconsolidated operations from favorable changes in the mix of customer requirements.

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
		2020		2019		2020		2019			2021		2020		2021		2020
Revenues	Revenues	$	2,722	$	5,022	$	9,950	$	25,950	Revenues	$	5,608	$	1,987	$	11,108	$	7,228
Cost of sales	Cost of sales	537		814		1,793		2,902		Cost of sales	956		558		1,643		1,256
Gross profit	Gross profit	2,185		4,208		8,157		23,048		Gross profit	4,652		1,429		9,465		5,972
Selling, general and administrative expenses	Selling, general and administrative expenses	512		308		1,707		690		Selling, general and administrative expenses	479		919		1,057		1,195

Operating profit	Operating profit	$	1,673	$	3,900	$	6,450	$	22,358	Operating profit	$	4,173	$	510	$	8,408	$	4,777

Revenues and operating profit ~~decreased~~increased significantly in the three and ~~nine~~six months ended ~~September~~June 30, ~~2020~~2021 compared with the ~~2019~~respective 2020 periods. The first ~~nine months~~half of ~~2019~~2021 included ~~significant~~an increase in royalty income generated by ~~a large number~~gas production from the Ohio minerals interests, as well as oil production from the Permian Basin and Eagle Ford Shale mineral interests acquired in the fourth quarter of ~~new gas wells put into commission during 2018~~2020 and early ~~2019. These wells are operated by third parties to extract~~in the second quarter of 2021, respectively. Favorable changes in natural gas ~~from the Company's Ohio Utica shale mineral reserves. Since new wells have high initial production rates~~ and ~~follow a natural decline before settling into relatively stable, long-term production, royalty income in 2020 decreased substantially from 2019 levels. Lower commodity~~oil prices ~~in 2020 compared with 2019~~ also contributed to the ~~reduction~~improvement in revenues and operating profit. The ~~increase~~decrease in selling, general and administrative expenses is primarily due to a $0.5 million charge in the ~~first nine months~~second quarter of 2020 to write-off certain leasehold interests.

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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
2020 2019 2020 2019
Operating loss $ (3,693) $ (5,371) $ (12,366) (15,179)

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	THREE MONTHS				SIX MONTHS
	2021		2020		2021		2020
Operating loss	$	(4,828)	$	(4,070)	$	(9,547)	(8,673)

~~Operating~~The operating loss ~~decreased~~increased in the three and ~~nine~~six months ended ~~September~~June 30, ~~2020 compared with the 2019 periods~~2021 primarily due to ~~lower~~business development initiatives and higher employee-related ~~expenses.~~costs.

NACCO Industries, Inc. Outlook

Coal Mining Outlook - ~~2020~~2021

In the second half and for the full year of 2021, the Company expects coal deliveries to decrease moderately from the respective prior year periods based on current expectations of customer requirements.

Despite the anticipated decrease in tons delivered, the Company expects operating profit for the Coal ~~deliveries~~Mining segment to increase significantly in both the second half and for the full year of 2021 due to the anticipated cash receipt of approximately $24 million related to the termination of the Falkirk and Bisti customer contracts previously discussed. In addition, the fourth quarter of 2020 included charges totaling $4.6 million that are not expected to reoccur. Excluding the impact of these items, operating profit in the second half and for the full year of 2021 is expected to decrease from the respective prior year periods. The decrease is primarily attributable to substantially lower earnings expected at MLMC and reduced earnings at the unconsolidated Coal Mining operations.

MLMC earnings are expected to decrease in the second half of 2021 from the comparable 2020 period and the first six months of 2021. This expected decrease is due to an anticipated decline in the profit per ton of coal delivered, due in part to an increase in depreciation expense from higher capital expenditures in years subsequent to 2019. As a result of the anticipated decrease in profit per ton, the 2021 full year results are expected to be ~~comparable to~~lower than the ~~fourth quarter of 2019. Despite comparable deliveries, fourth-quarter~~ 2020 ~~operating profit is expected to decrease compared with the 2019 fourth quarter.~~ full year.

The ~~decrease in operating profit is mainly due to an~~ anticipated ~~reduction in results at MLMC and a~~ reduction in earnings at the unconsolidated ~~mining operations.~~

~~Results at MLMC are expected to decline significantly from the fourth quarter of 2019 primarily due to an increase in the cost per ton delivered.~~

~~Overall, full-year 2020 coal deliveries and operating profit are~~Coal Mining operations is expected to be ~~lower than 2019,~~ mainly driven by a reduction in fees earned at the Liberty Mine, as the scope of final mine reclamation declines compared with 2020, reduced earnings at Bisti as a result of ~~a decrease in~~the contract termination effective September 30, 2021, and lower earnings at the unconsolidated mining operations due to reduced customer requirements and the termination of the Camino Real contract mining agreement. As mentioned above, the contract between Camino Real and its customer, DRCP was unexpectedly terminated effective July 1, 2020 and the mine was closed.

During the third quarter of 2020, Sabine’s customer, American Electric Power, reduced its annual lignite coal requirements to be between 1.4 million and 1.7 million tons compared with 2.6 million tons delivered in 2019. The customer reduced its expected future requirements because the plant servedFalkirk, partially offset by ~~the Sabine Mine was dispatched~~improved earnings at ~~a much lower rate in 2020 than in 2019, and that trend is expected to continue.~~

On September 30, 2020, the Company's Caddo Creek's customer entered into an agreement for the sale of their activated carbon manufacturing business, including its Marshall Mine operated by Caddo Creek, to a subsidiary of AES. AES announced its intent to close the mine, which delivered 0.2 million tons in 2019. Caddo Creek has entered into a contract to perform the required mine reclamation.

Coteau. Changes in customer power plant dispatch, including changes ~~due~~related to ~~historically low~~ natural gas ~~prices~~price fluctuations and the continued increase in renewable generation, particularly wind, could reduce customer demand below anticipated levels, which could further unfavorably affect the Company’s ~~fourth quarter~~second-half and full-year ~~2020 results, as well as its~~ 2021 outlook.

~~Coal Mining Outlook -~~Excluding the $24 million termination-related payments expected in the second half of 2021

In and the $1.1 million asset impairment charge recognized in 2020, Segment adjusted EBITDA for the second half of 2021 is expected to decrease from the ~~Company expects coal deliveries~~second half of 2020 as a result of the reduction in operating profit. Segment adjusted EBITDA for the full year is expected to be comparable to 2020 ~~based on current expectations of customer requirements.~~

~~Coal Mining~~as the reduction in operating profit in 2021 is expected to decrease compared with 2020, mainly in the first half of the year. This decrease is primarily the result of an expected increase in operating expenses and an anticipated reduction in earnings at the unconsolidated Coal Mining operations primarily due to a contractually agreed reduction in fee-based earnings at the Liberty Mine as the scope of final mine reclamation activities is reduced.

~~Results at the consolidated mining operations are expected to be comparable between years, as a decrease in earnings at MLMC is expected to~~will be offset by ~~a lower operating loss at Centennial. At MLMC, results are expected to be lower due to~~ an increase in the cost per ton of coal delivered in 2021 compared with 2020. In general, cost per ton delivered is lowest when the power plant requires a consistently high level of coal deliveries, primarily because costs are spread over more tons.

On May 7, 2020, GRE, Falkirk Mine's customer and the Company's second largest customer, announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and modify the Spiritwood Station power plant to be fueled by natural gas. GRE is willing to consider opportunities to sell Coal Creek Station, and NACCO is actively engaged in the exploration of options that could, if successful, allow for transfer of ownership of the power plant to one or more third parties, which would preserve jobs at both Coal Creek Station and the Falkirk Mine.

Falkirk Mine is the sole supplier of lignite coal to Coal Creek Station pursuant to a long-term contract under which Falkirk also supplies a moderate amount of lignite coal annually to Spiritwood Station. In 2019, Falkirk contributed approximately $16 million to NACCO’s Earnings from Unconsolidated Operations. The closure of Coal Creek Station will have a material adverse effect on the long-term earnings of NACCO Industries. The terms of the contract between the Company and GRE specify that

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GRE is responsible for all costs related to mine closure, including but not limited to, final mine reclamation costs, post-retirement medical benefits and pension costs with respect to Falkirk employees.depreciation expense.

Capital expenditures are expected to be approximately ~~$12~~$21 million in the ~~fourth quarter~~second half of ~~2020~~2021 and approximately ~~$20~~$26 million for the ~~2020~~ full ~~year, and approximately $24 million in 2021.~~year. The ~~Company expects high~~elevated levels of capital expenditures in the ~~remainder of 2020 and in~~Coal Mining segment expected through 2021 ~~primarily related~~relate to ~~MLMC's~~the development of a new mine ~~area. These~~area at MLMC. The increase in capital expenditures associated with mine development will result in ~~an increase~~higher depreciation expense in ~~depreciation~~future periods that will unfavorably affect future operating ~~profit~~profit. Capital expenditures for MLMC are expected to return to lower pre-2019 levels in 2022.

Premature closure or reduction in utilization of power plants served by the Company's mines would have a material adverse effect on the future ~~periods.~~Earnings of unconsolidated operations of the Coal Mining segment and on the long-term earnings and cash flows of NACCO. The owner of the power plant served by the Company's Sabine Mine in Texas intends to retire the power plant in 2023. Deliveries from Sabine to the power plant are expected to continue until the first quarter of 2023 at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the responsibility of the customer. Coteau operates the Freedom Mine in North Dakota. All coal production from the Freedom Mine is delivered to Basin Electric Power Cooperative. Basin Electric utilizes the coal at the Great Plains Synfuels Plant, Antelope Valley Station and Leland Olds Station. The Synfuels Plant is a coal gasification plant that manufactures synthetic natural gas and produces fertilizers, solvents,

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phenol, carbon dioxide, and other chemical products for sale. In June 2021, Basin Electric announced it was evaluating the Synfuels Plant for possible sale.

NAMining Outlook

~~In the fourth quarter of 2020,~~ NAMining expects ~~limestone deliveries~~tons delivered, operating profit and Segment adjusted EBITDA to increase ~~moderately~~in the second half of 2021 over the ~~fourth quarter~~second half of ~~2019, resulting in~~2020. Tons delivered and operating profit are expected to be higher primarily as a result of increased production under existing contracts and contributions from new mining contracts, partially offset by an ~~overall modest~~ increase in ~~tons delivered for the 2020 full year compared with full-year 2019.~~

~~NAMining expects~~ operating ~~profit in the fourth quarter of 2020~~expenses mainly due to improve substantially over the fourth quarter of 2019, but less significantly than in the previous three quarters of 2020. Operating profit is expected to benefit from favorable changes in the mix of customer requirements.higher employee-related costs, including medical costs, and anticipated higher business development expenses. Full-year ~~2020~~2021 operating profit is expected to decrease moderately compared with 2020 because of the lower first-quarter 2021 results. Segment adjusted EBITDA for the full year is expected to increase ~~significantly over 2019. In~~compared with 2020 as the moderate reduction in operating profit will be more than offset by an increase in depreciation expense.

During the first quarter of 2021, NAMining ~~expects full year~~entered into a 15-year mining services contract with a new customer at a limestone quarry in Central Florida. NAMining is operating ~~profit~~a smaller dragline at this quarry for the next two years while it relocates and commissions a larger dragline that will increase production capacity. Deliveries are expected to be ~~comparable~~approximately 1.5 million tons annually once mining commences with the larger dragline, which is anticipated to ~~2020~~occur in 2023. NAMining also amended a contract with ~~its~~a current customer to operate an additional dragline at an existing limestone quarry in Florida. Early in the second quarter of 2021, NAMining entered into a one-year mining services contract with an existing customer ~~contracts.~~for a sand and gravel quarry in Indiana. This customer, which is among the largest aggregates producers in the United States, is hopeful that this new quarry will operate for multiple years providing aggregates for a multi-year transportation infrastructure project near Indianapolis. Deliveries are expected to be between 0.6 million to 1.0 million tons during the term of the agreement. NAMining anticipates that these new or revised contracts will be accretive to earnings in the second half of 2021. NAMining has a substantial pipeline of potential new projects and is pursuing a number of growth initiatives that if successful would be accretive to future earnings.

~~Capital expenditures~~In late July 2021, NAMining signed two contracts with a new customer to perform all mining operations at two sand and gravel quarries located in Texas and Arkansas. The initial term of each contract is two years, and one of the contracts automatically extends an additional two years provided NAMining is not in default under that contract. This customer is a leading supplier of construction materials in North America. These contracts are expected to be ~~approximately $3 million~~accretive to future earnings, but due to the timing of contract execution are not included in the ~~fourth quarter~~Company’s discussion of ~~2020 and approximately $13 million and $7~~outlook for the 2021 second half or full year.

NAMining originally forecasted capital expenditures of $10 million for 2021. NAMining now expects full-year capital expenditures to be $25 million, with approximately $19 million expended in the ~~2020 full year and 2021, respectively, primarily~~second half of 2021. In addition to capital expenditures for the acquisition, relocation and refurbishment of ~~draglines.~~draglines, forecasted capital expenditures now include the acquisition of other mining equipment to support the expansion of contract-mining services beyond NAMining's historical dragline-oriented model.

In 2019, NAMining's subsidiary, Sawtooth Mining, LLC, entered into a mining 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 Nevada is in~~All major permits for the ~~process~~Thacker Pass Project are expected to be received by the end of ~~securing permits and currently expects to commence construction in 2021 and production of lithium products in 2023.~~2021.

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, ~~and, to a lesser extent,~~ oil, natural gas liquids and coal, extracted primarily by third parties. ~~The 2019 results included a substantial increase in royalty income, primarily~~

In 2020, Minerals Management took impairment charges totaling $7.3 million, $0.6 million and $6.7 million in the ~~first nine months~~second and fourth quarters, respectively, related to coal-related legacy assets. Excluding these charges, operating profit and Segment adjusted EBITDA in the Minerals Management segment is expected to decrease significantly in the second half of ~~2019, generated by a large number~~2021 from the second half of ~~new gas wells put into commission during 2018 and early 2019. Given expected lower natural gas prices, fewer expected new wells, lower commodity prices and~~2020 primarily due to the natural production decline ~~that occurs early~~curve of certain newer wells in Ohio. Royalty income generated from the life of a well, fourth quarter and full-year 2020 royalty income is expected to be substantially lower than 2019 levels. Given these factors, royalty income from existing assets is also expected to be down substantially in 2021 from 2020. A sustained decline in natural gas prices could unfavorably affect the Company’s outlook.

Decline rates for individual wells can vary due to factors like well depth, well length, formation pressure and facility design. In addition, royalty income can fluctuate favorably or unfavorably in response to a number of factors outside of the Company's control, including the number of wells being operated by third parties, fluctuations in commodity prices (primarily natural gas), fluctuations in production rates associated with operator decisions, regulatory risks, the Company's lessees' willingness and ability to incur well-development and other operating costs, and changes in the availability and continuing development of infrastructure.

~~Minerals Management is targeting investments in~~Permian Basin mineral ~~and royalty~~ interests ~~of approximately $15 million~~acquired in the fourth quarter of 2020 and ~~$10~~the Eagle Ford Shale in May 2021, in addition to favorable changes in oil and gas market pricing, are expected to partly offset the reduced earnings in the second half of the year, and contribute to the expected increase in full-year 2021 operating profit and Segment adjusted EBITDA over 2020.

Minerals Management began 2021 with a plan to make investments in mineral and royalty interests totaling approximately $10.5 million. As part of this strategy, Minerals Management completed acquisitions totaling $5.0 million for interests in the Eagle Ford Shale early in the second quarter of 2021. Minerals Management is targeting to acquire additional similar investments of approximately $5.0 million in ~~2021, although~~ the ~~timing~~second half of ~~the fourth quarter investments could slip into~~ 2021. These investments, in addition to the Permian Basin

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interests acquired late in 2020, are expected to continue to be accretive, ~~to earnings,~~ but each investment's contribution to earnings is dependent on the ~~timing,~~details of each investment, including the size and type of interests acquired and the stage and timing of mineral development. ~~The Company's~~

These acquired interests align with the Company’s strategy ~~is to~~of selectively ~~acquire oil and gas~~acquiring mineral and royalty interests with a balance of near-term, ~~cash flow~~cash-flow yields and long-term growth potential, in oil-rich basins offering diversification from the ~~Company's~~Company’s legacy mineral ~~interest in predominantly natural gas-rich basins.~~interests.

Consolidated 2021 Outlook

~~Overall, NACCO expects a modest increase in consolidated operating profit~~Management continues to view the long-term business outlook positively. The long-term outlook for growth in the ~~fourth quarter of 2020 over 2019, which included a $2.0 million unfavorable mine reclamation adjustment~~NAMining and Minerals Management segments and in the ~~Coal Mining segment. Excluding this adjustment, fourth-quarter 2020 consolidated operating profit~~Company's Mitigation Resources of North America® business is strong. Each of these businesses continues to expand its pipeline of potential new projects with opportunities for growth and diversification. In the first half of 2021, NAMining executed three new agreements and Minerals Management completed two acquisitions, demonstrating success in executing on their growth strategies.

The Company expects net income ~~are expected~~for the 2021 full year to ~~decrease~~be significantly higher than 2020, with an anticipated effective income tax rate between 13% and 15%, both resulting from the ~~prior year, primarily~~expected termination and release settlements associated with Falkirk and Bisti and the absence of the prior-year charges totaling $12.1 million. Excluding these items, the Company expects significantly lower net income in 2021 as a result of ~~anticipated~~substantially lower ~~results in the Coal Mining segment and an increase in income tax expense, partially offset by lower unallocated employee-related costs.~~

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~~The Company expects a significant decrease in full-year 2020 consolidated~~ operating profit ~~and net income compared with 2019,~~ primarily due to the substantial decrease in operating profit at Minerals Management in the first nine months of 2020 and the anticipated reduction in full-year earnings at the Coal Mining segment. In addition, the Company received a final settlement associated with a prior India venture in 2020 that was less than the initial award received in 2019. These items are expected to be partially offset by an improvement in earnings at the NAMining segment and an anticipated lower effective income tax rate in 2020 compared with 2019. For the full year, NACCO anticipates that its 2020 effective income tax rate will be in the range of 5% to 7% based on the current forecasted mix of earnings.

Consolidated capital expenditures are expected to be approximately $30 million in the fourth quarter of 2020 and approximately $50 million for the full year. As a result of the increase in capital expenditures and payments made in the first half of the year related to deferred compensation and other payroll liabilities, consolidated cash flow before financing activities is expected to be a significant use of cash in the 2020 full year.

~~In 2021, NACCO expects consolidated net income to decrease~~ significantly ~~from 2020. An anticipated reduction in earnings in the Minerals Management segment and~~ lower earnings in the Coal Mining segment ~~are~~and higher unallocated employee-related and business development costs. Consolidated Adjusted EBITDA in 2021 is expected to ~~be partially offset by lower income tax expense as~~increase moderately over 2020, excluding the termination and release payments and prior-year impairment charges.

As a result of the termination and release payments, the Company expects ~~the full-year 2021 effective income tax rate to be between negative 5% and negative 7%.~~

In light of ongoing regulatory, economic and public opinion challenges facing the coal-fired power generation industry, the Company commenced a voluntary retirement program for certain corporate employees in the fourth quarter. The program is expected to be substantially completed by December 31, 2020 and reduce general and administrative expenses in 2021 and future years. The amount of savings, and related one-time separation costs, will depend on the level of participation in the program.

~~Cash~~positive cash flow before financing activities ~~is expected to improve and be a solid generation of cash~~ in 2021 as compared ~~with~~to a significant use of cash in 2020, but ~~not to~~at a level below the ~~level realized~~amount of cash generated in 2019. Consolidated capital expenditures are expected to be approximately ~~$41~~$61 million in ~~2021, primarily consisting of $24 million in the Coal Mining segment, $10 million in the Minerals Management segment and $7 million in the NAMining segment.~~2021.

~~Significant uncertainties exist regarding the COVID-19 pandemic, including the extent of economic disruption it may cause in the future.~~ The extent to which COVID-19 impacts the Company going forward will depend on numerous factors, including but not limited to the duration of the ongoing pandemic, the severity of the COVID-19 variants, the effectiveness of actions taken to contain and ~~future developments that remain uncertain.~~treat COVID-19 and its variants, the nature of, and the public's adherence to, public health guidelines, the pace and acceptance of vaccinations and subsequent achievement of herd immunity, as well as the severity of pandemic-related supply chain and cost inflation challenges and the pace and the extent of economic recovery. While the Company's ~~mining~~existing operations to date have not been ~~directly~~materially affected by the pandemic, future developments, which are highly uncertain and unpredictable, could significantly and rapidly cause a deterioration in the Company’s results, supply chain channels and customer demand. The extent to which COVID-19 may adversely impact the Company depends on many factors, including but not limited to the extent of new outbreaks, the extent to which additional shutdowns may be imposed, the nature of the government public health guidelines and the public's adherence to those guidelines, the success of businesses reopening fully, and the timing for proven treatments and vaccines for COVID-19. NACCO continues to maintain procedures to limit the exposure of employees to COVID-19. Even after the COVID-19 pandemic has subsided, the Company may experience material adverse effects due to a resulting decline in economic activity. Additionally, concerns over the economic impact of COVID-19 have caused extreme volatility in financial and other capital markets and may adversely impact NACCO's stock price.

~~One~~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.

NAMining is pursuing growth and diversification by expanding the scope 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 ~~strategies~~mining skills to expand the range of contract mining services it provides. NAMining advanced these efforts in early 2021, when it entered into a contract to mine sand and gravel in Indiana, and in mid-2021, when it signed contracts with a leading supplier of construction materials in North America to perform all mining operations at two sand and gravel quarries located in Texas and Arkansas. The new contracts include responsibility for all mining activities, including pre-strip, blasting, excavation and load and haul operations. These new contracts expand the range of contract mining services beyond the traditional scope of NAMining's core limestone mining business and expand its geography beyond Florida. In addition, NAMining continues to pursue additional opportunities to provide comprehensive mining services to operate entire mines, as it expects to do at the new lithium project in Nevada. The goal is to build NAMining into a leading provider of contract mining services for customers who 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 capital in the mid-teens as this business model matures and achieves significant scale.

The Minerals Management segment continues its efforts to grow and diversify by pursuing acquisitions of additional mineral and royalty interests in the United States, in what the Company believes is a buyer-friendly market. Once mineral and royalty interests have been acquired, the Minerals Management segment will benefit from the continued development of its mineral properties without additional capital investment. 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

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mineral and royalty interests, has developed a strong network to source and secure new acquisitions, and has a pipeline of potential acquisitions under review. The goal is to construct a diversified portfolio of high-quality oil, gas, mineral and royalty interests in the United States that deliver 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 as the portfolio of reserves and mineral interests grows and this business model matures.

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. This business offers opportunity for growth and diversification in an industry where the Company has substantial knowledge and expertise and a strong reputation. The Mitigation Resources business has achieved several early successes and is positioned for additional growth. The Company's goal is to grow Mitigation Resources into one of the ten largest U.S. providers of mitigation solutions, largely focused on streams and wetlands, initially in the southeast United States. While this business is in the early stages of development, the Company believes that Mitigation Resources can provide solid rates of return as this business matures.

The Company also continues to pursue activities which can strengthen the resiliency of its existing coal mining operations. The Company ~~works to drive down~~remains focused on managing coal production costs and ~~maximize~~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.

The Company continues to ~~evaluate~~look for opportunities to expand its coal mining business ~~however~~where it can apply its management fee business model to assume operation of existing surface coal mining operations in the United States. However, opportunities are ~~likely to be~~ very ~~limited. Low~~limited in the current environment. Fluctuating natural gas prices and growth in renewable energy sources, such as wind and solar, are likely to continue to unfavorably affect the amount of electricity dispatched from coal-fired power plants. ~~The~~In addition, the political and regulatory environment is not receptive to development of new coal-fired power generation projects which would create opportunities to build and operate new coal mines. However, the Company does continue to seek out and pursue opportunities where it can apply its management fee business model to assume operation of existing surface coal mining operations in the United States. Outright acquisitions of existing coal mines or mining companies with exposure to fluctuating coal commodity markets, or structures that would create significant leverage, are outside the Company’s area of focus.

The Company is focused on building a strong portfolio of affiliated businesses for diversification. NAMining continues to expand the scope of its business development activities to grow and diversify by targeting potential customers who require a

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broad range of minerals and materials. NAMining also continues to leverage the Company’s core mining skills to expand the range of contract mining services provided, in addition to providing comprehensive mining services to operate entire mines when appropriate, as is the case at the new lithium project in Nevada.

The Company’s efforts to grow and diversify the Minerals Management segment includes acquiring additional mineral interests or similar investments in the energy industry. During the second quarter of 2020, the Company’s subsidiary, Catapult Mineral Partners, invested $2.0 million to acquire shares of a public company with a diversified portfolio of royalty producing mineral interests as part of this growth and diversification strategy. The recent dramatic downturn in petroleum prices provided an opportunity to make this investment at an attractive market multiple for a company with a conservative financial position, strong earnings potential and attractive historical dividend yield.

~~Mitigation Resources of North America~~® was formed to create and sell stream and wetland mitigation credits and provide services to those engaged in permittee-responsible mitigation. This business has achieved several early successes and is positioned for additional growth.

The Company is leveraging its core mining and natural resources management skills to develop a strong and diverse portfolio of service-based businesses operating in the mining and natural resources industries. The Company is also committed to maintaining a conservative capital structure as it continues to grow and diversify, while ~~it grows and diversifies without~~avoiding unnecessary risk. ~~Ultimately, diversified strategic growth is the key to increasing~~Strategic diversification will allow for increased free cash flow ~~available~~that can be re-invested to ~~continue to re-invest in~~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.

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 ~~a long-term mining contract,~~customer or other third-party contracts, or a customer or other third party default under a contract, ~~including any actions taken related to GRE's Coal Creek Station power plant,~~ (2) ~~the duration and severity of the COVID-19 pandemic, any preventive or protective actions taken~~a significant reduction in purchases by ~~governmental authorities, the effectiveness of actions taken globally to contain or mitigate its effects and any unfavorable effects of the COVID-19 pandemic on~~ the Company's ~~suppliers' ability to provide products or replacement parts if the virus continues to spread or quarantines are reinstated, as well as other disruptions from natural or human causes,~~customers, including ~~severe weather, accidents, fires, earthquakes, terrorist acts, any of which could result in suspension of operations or harm to people or the environment, (3)~~ 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, (3) 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, (4) failure to obtain adequate insurance coverages at reasonable rates, (5) the impact of the COVID-19 pandemic, (6) 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, ~~(5)~~(7) changes in costs related to geological and geotechnical conditions, repairs and maintenance, new equipment and replacement parts, fuel or other similar items, ~~(6)~~(8) regulatory actions, changes in mining permit requirements or delays in obtaining mining permits that could affect deliveries to customers, ~~(7)~~(9) weather conditions, extended power plant outages, liquidity events or other events that would change the level of customers' coal or aggregates requirements, ~~(8)~~(10) weather or equipment problems that could affect deliveries to customers, ~~(9)~~(11) 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~~well-development operations and leasing and development ~~operations, (10)~~of oil and gas reserves on federal lands, (12) changes in the costs to reclaim mining areas, ~~(11)~~(13) costs to pursue and develop new mining and value-added service opportunities, ~~(12)~~(14) delays or reductions in coal or aggregates deliveries, ~~(13)~~(15) changes in the prices of hydrocarbons, particularly diesel fuel, natural gas and oil, ~~(14)~~(16) the ability to successfully evaluate

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investments and achieve intended financial results in new business and growth initiatives, ~~(15)~~(17) the effects of ~~receiving low sustainability scores~~investors’ and other stakeholders’ increasing attention to environmental, social and governance (“ESG”) matters, and (18) 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 ~~exclusion of the Company's securities from consideration by certain investment funds, and (16) failure to obtain adequate insurance coverages.~~environment.

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.

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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.

Changes in internal control over financial reporting: During the ~~third~~second quarter of ~~2020,~~2021, 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, ~~2020,~~2021, 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, ~~2019, except as follows:~~

The Company’s results of operations, financial condition, cash flows and stock price could be adversely affected by pandemics, epidemics or other public health emergencies, such as the global outbreak of COVID-19. The COVID-19 pandemic resulted in governments around the world implementing stringent measures to help control the spread of the virus, including quarantines, "shelter in place" and "stay at home" orders, travel restrictions, business curtailments, school closures, and other measures.

The Company has continued to operate as an essential business because it supports critical infrastructure industries, as defined by the U.S. Department of Homeland Security. Although the Company has continued to operate facilities consistent with federal guidelines and state and local orders, the ongoing COVID-19 pandemic and the preventive or protective actions taken by governmental authorities may have a material adverse effect on the Company’s operations, work force, supply chain or customers, including business shutdowns or disruptions. The extent to which COVID-19 may adversely impact the Company's businesses depends on future developments, which are highly uncertain and unpredictable, including the extent of new outbreaks, the extent to which additional actions to mitigate the COVID-19 pandemic may be needed, the nature of government public health guidelines and the public's adherence to those guidelines, and the timing for proven treatments and vaccines for COVID-19. Any resulting financial impact cannot reasonably be estimated at this time, but could have a material adverse effect on the Company’s financial condition, cash flows and results of operations.

Even after the COVID-19 pandemic has subsided, the Company may experience material adverse effects due to a decline in economic activity. Additionally, concerns over the economic impact of COVID-19 have caused extreme volatility in financial and other capital markets which has and may continue to adversely impact NACCO's stock price.

~~Termination of or default under long-term mining contracts could materially reduce the Company's profitability.~~

Substantially all of the Coal Mining segment's profits are derived from long-term mining contracts. Although the Company has long-term contracts, numerous political and regulatory authorities, along with well-funded environmental activist groups, are devoting substantial resources to anti-coal activities to minimize or eliminate the use of coal as a source of electricity generation or other combustive uses. As a result of such activities, the Coal Mining segment's customers could prematurely retire certain coal-fired generating units or other facilities that combust coal. Any customers' premature facility closure could have a material adverse effect on the Company’s business, financial condition and results of operations.

On May 7, 2020, Great River Energy ("GRE"), Falkirk Mine's customer, and the Company's second largest customer, announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and modify the Spiritwood Station power plant to be fueled by natural gas.

Falkirk Mine is the sole supplier of lignite coal to Coal Creek Station pursuant to a long-term contract under which Falkirk also supplies approximately 0.3 million tons of lignite coal per year to Spiritwood Station. Falkirk has approximately 480 employees, and, in 2019, delivered a total of 7.4 million tons of lignite coal and contributed approximately $16 million to NACCO’s Earnings from Unconsolidated Operations. The closure of Coal Creek Station would have a material adverse effect on the long-term earnings of NACCO. The terms of the contract between the Company and GRE specify that GRE is responsible for all costs related to mine closure, including but not limited to final mine reclamation costs, post-retirement medical benefits and pension costs with respect to Falkirk employees.

Also noted in GRE’s announcement is their plan to negotiate an agreement to terminate their steam and water supply contract with Blue Flint, an ethanol biorefinery fueled by process steam from Coal Creek Station. Blue Flint’s owner,

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Midwest AgEnergy, is considering using the contract termination payment from Great River Energy to reinvest in an economical alternate source for its process heat. NACCO has a $5.0 million investment in Midwest AgEnergy. If Midwest AgEnergy is unable to find an economical alternate source for its process heat, the Company’s investment could become impaired.

State implementation of the EPA’s Regional Haze Rule (“RHR”) could require Coyote Creek’s customers to incur significant new costs at the Coyote Station power plant, which could, dependent on determinations by state regulatory commissions on approval to recover such costs from Coyote Creek’s customer’s customers, negatively impact Coyote Creek’s customers’ net income, financial position and cash flows. The Company understands that the North Dakota Department of Environmental Quality (“NDDEQ”) could require sources subject to RHR Round 2 reasonable progress determinations, including Coyote Station, to undertake emissions control measures. If NDDEQ requires significant emissions controls at Coyote Station by December 31, 2028, it may not be economically feasible for Coyote Creek's customers to invest in such equipment and an early retirement of Coyote Station and the Coyote Creek mine could be necessary. NDDEQ’s state implementation plan is due to be submitted to the EPA by July 2021. Preliminary modeling favors minimal additional emissions control measures for all North Dakota sources. The Company expects the NDDEQ to further evaluate additional preliminary control scenarios for regional visibility modeling in the second half of 2020 and prepare a draft state implementation plan available for public comment the first half of 2021.

Under certain circumstances of default or termination of Coyote Creek’s Lignite Sales Agreement (“LSA”), the Company 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 or after January 1, 2024 by Coyote Creek’s customers, the Company is obligated to purchase Coyote Creek’s dragline and rolling stock for the then net book value of those assets. Any decision by Coyote Creek’s customers to reduce operations or prematurely close the Coyote mine would have a material adverse effect on the Company’s results of operations, financial position and cash flows.

Mississippi Lignite Mining Company ("MLMC") is subject to risks associated with its capital investment, operating and equipment costs, growing use of alternative power generation that competes with coal-fired power generation, changes in customer demand and inflationary adjustments.

The 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. In addition, MLMC sells lignite at contractually agreed upon prices which are subject to changes in the level of established indices over time. The price of diesel fuel is heavily-weighted among these indices. As such, a substantial decline in diesel prices could materially reduce MLMC's profitability, as the decline in revenue will only be partially offset by the effect of lower diesel prices on production costs.

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 PPA. 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 ("IRP"). The IRP indicates TVA 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 which power plants to dispatch is determined by TVA. TVA has dispatched Red Hills Power Plant at a lower rate in the last two years than in prior years.

Choctaw Generation Limited Partnership ("CGLP") leases the Red Hills Power Plant from a Southern Company subsidiary pursuant to a leveraged lease arrangement. The ability of the lessee to make required payments to the Southern Company subsidiary is dependent on the operational performance of the Red Hills Power Plant. Southern Company recently publicly disclosed that while all CGLP lease payments have been paid in full through June 30, 2020, operational and other risks have resulted in cash liquidity challenges at the Red Hills Power Plant, and based on current forecasts of energy prices in the years following the expiration of the PPA in 2032, concerns exist regarding the lessee's ability to make the remaining semi-annual lease payments through the end of the lease term in 2047. During the fourth quarter of 2019, Southern Company concluded that it was no longer probable that all of the payments would be received over the term of the lease and therefore recognized an impairment charge to reduce the value of the lease investment. During the second quarter of 2020, Southern Company revised the estimated cash flows

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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 financial condition, results of operations and cash flows.

Similar to the Company's unconsolidated mines, all production costs at MLMC are capitalized into inventory and recognized in cost 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 or net realizable value approach, which could adversely affect MLMC’s results of operations.

Changes in customer demand 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.

~~Changes in coal consumption patterns of U.S. electric power generators could adversely affect the Company's profitability.~~

The amount of coal consumed by the electric power generation industry is affected by general economic conditions; overall demand for electricity; availability of transmission; competition from alternative fuel sources for power generation, such as natural gas, nuclear, hydroelectric, wind and solar power, and the location, availability, quality and price of those alternative fuel sources; environmental and other governmental regulations, including those impacting coal-fired power plants; and energy conservation efforts and related governmental policies.

Changes in the utility and coal mining industry that affect our customers could also adversely affect the Company. Lower natural gas prices and increased availability of renewables have contributed to a reduction in demand for coal-fired electric power generation. Competition from natural gas-fired plants that are relatively more efficient, less expensive to construct and less difficult to permit than coal-fired plants has the most potential to continue to displace a significant amount of coal-fired electric power generation in the near term. Federal and state mandates for increased use of electricity derived from renewable energy sources have also adversely affected demand for coal-fired electric power generation. Such mandates make alternative fuel sources more competitive with coal-fired electric power generation.

The outcome of the 2020 U.S. presidential election could result in a shift in the regulatory environment that is impossible to predict at this time. Changes in federal and state mandates that would include an acceleration in the use of electricity derived from renewable energy sources could result in a decrease in coal consumption by the electric power generation industry and the Company’s customers.

A decrease in coal consumption by the electric power generation industry and the Company’s customers could have a material adverse effect on the Company’s business, financial condition and results of operations.

Insurance coverage is increasingly expensive, contains more stringent terms and may be difficult to obtain in the future. A number of global insurance companies have taken action to limit coverage for companies in the coal mining industry, which could result in significant increases in costs of insurance or in the Company’s ability to maintain insurance coverage at current levels.

The Company holds a number of insurance policies, including director and officers’ liability and property and casualty insurance coverages. Because the Company is involved in the coal mining industry, costs of insurance may increase substantially or insurance carriers may decide not to insure the Company in the future. In addition, if the Company makes significant insurance claims, its ability to obtain future insurance coverage at commercially reasonable rates could be materially adversely affected. An inability to obtain insurance coverage, significant increases in the premiums or deductibles of insurance the Company obtains, or losses in excess of its liability insurance coverage limits, which may go down in the future, could have a material adverse effect on the Company's operating results and financial condition.

Increasing scrutiny and changing expectations with respect to the Company’s environmental, social and governance practices may impose additional costs on the Company or expose the Company to new or additional risks.

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Companies across all industries are facing increasing scrutiny from stakeholders related to their environmental, social and governance (“ESG”) practices. Investor advocacy groups, certain institutional investors, investment funds and other influential investors are also increasingly focused on ESG practices. Regardless of the industry, investors’ and others increased focus and activism related to ESG and similar matters may hinder access to capital, insurance and other financial products as third parties may decide to reallocate capital or to not commit capital or risk management products as a result of their assessment of a company’s ESG practices. Companies which do not adapt to or comply with investor or stakeholder expectations and standards, which are evolving, or which are perceived to have not responded appropriately, regardless of whether there is a legal requirement to do so, may suffer from reputational damage and the business, financial condition, and/or stock price of such a company could be materially and adversely affected.

The Company could face pressures from investors, who are increasingly focused on climate change, to prioritize sustainable energy practices, reduce the Company’s carbon footprint and promote sustainability. Investors may request the Company implement ESG procedures or standards as a condition to maintain their investment or to make further investments. Additionally, the Company may face reputational challenges in the event its ESG practices are inconsistent with the third party views of acceptable ESG practices.2020.

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		(c) Total Number of Shares Purchased as Part of the Publicly Announced Program	(d) Maximum Dollar Value of Shares that May Yet Be Purchased Under the Program (1)
Month #1 (~~July~~April 1 to ~~31, 2020)~~30, 2021)	—	$	—	—	$	22,659,516
Month #2 (~~August~~May 1 to 31, ~~2020)~~2021)	—	$	—	—	$	22,659,516
Month #3 (~~September~~June 1 to 30, ~~2020)~~2021)	—	$	—	—	$	22,659,516
Total	—	$	—	—	$	22,659,516

(1) ~~In November~~During 2019, the Company established a stock repurchase program allowing for the purchase of up to $25.0 million of the Company's Class A Common Stock outstanding through December 31, 2021. See Note 54 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, ~~2020.~~2021.

Item 5 Other Information

None.

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Item 6 Exhibits


Exhibit
Number*						Description of Exhibits

10.1						Coal Sales Agreement, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated June 30, 2021.***
10.2						Guaranty by REMC Assets, LP, dated June 17, 2021.***
10.3						Mortgage, Assignment of Leases, Rents and As-Extracted Collateral, Security Agreement, Financing Statement and Fixture Filing, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated June 30, 2021.***
10.4						Security Agreement, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated June 30, 2021.**
10.5						Option Agreement, by and between The Falkirk Mining Company, Rainbow Energy Center, LLC and the State of North Dakota, Doing Business as The Bank of North Dakota, dated June 30, 2021.**
10.6						Termination Agreement and Release, by and among The Falkirk Mining Company, Great River Energy and NoDak Energy Investments Corporation, dated June 30, 2021.**
10.7						NACCO Industries, Inc.'s Amended and Restated Executive Long-Term Incentive Compensation Plan (effective March 1, 2021) is incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by the Company on May 19, 2021, Commission File Number 1-9172.
10.8						NACCO Industries, Inc.'s Amended and Restated Non-Employee Directors' Equity Compensation Plan (effective May 19, 2021) is incorporated herein by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K, filed by the Company on May 19, 2021, 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.

*** Filed herewith, where certain confidential information contained in this agreement has been omitted because it (i) is not material and (ii) would be competitively harmful if publicly disclosed.

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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 2, 2020~~August 4, 2021	/s/ Elizabeth I. Loveman
		Elizabeth I. Loveman
		Vice President and Controller (principal financial and accounting officer)

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Description	Location	SEPTEMBER 30 2020		DECEMBER 31 2019
Assets
Operating	Operating lease right-of-use assets	$	10,448	$	11,398
Finance	Property, plant and equipment, net (a)	$	144	$	544


Liabilities
Current
Operating	Other current liabilities	$	1,296	$	1,318
Finance	Current maturities of long-term debt	$	44	$	558
Noncurrent
Operating	Operating lease liabilities	$	11,494	$	12,448
Finance	Long-term debt	$	103	$	85


	Finance Leases		Operating Leases		Total
Remainder of 2020	$	13	$	532	$	545
2021	49		2,113		2,162
2022	49		2,162		2,211
2023	28		1,685		1,713
2024	12		1,660		1,672
Subsequent to 2024	7		9,421		9,428
Total minimum lease payments	$	158	$	17,573	$	17,731
Amounts representing interest	11		4,783
Present value of net minimum lease payments	$	147	$	12,790


Expenditures for property, plant and equipment
Coal Mining	$	3,150	$	2,291	$	7,817	$	6,542
NAMining	3,220		4,971		10,406		6,213
Minerals Management	633		0		1,372		291
Unallocated Items	0		35		207		218
Total	$	7,003	$	7,297	$	19,802	$	13,264

Depreciation, depletion and amortization
Coal Mining	$	3,793	$	3,102	$	10,951	$	9,252
NAMining	723		588		2,021		1,699
Minerals Management	327		324		981		1,057
Unallocated Items	33		30		91		87
Total	$	4,876	$	4,044	$	14,044	$	12,095