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NC Nacco Industries

Filed: 3 Nov 21, 4:58pm

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 endedSeptember 30, 2021
OR
 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                     to                     
Commission file 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 shareNCNew 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 companyEmerging 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 29, 2021: 5,607,149
Number of shares of Class B Common Stock outstanding at October 29, 2021: 1,566,643



NACCO INDUSTRIES, INC.
TABLE OF CONTENTS

1

Part I
FINANCIAL INFORMATION
Item 1. Financial Statements

NACCO INDUSTRIES, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
 SEPTEMBER 30
2021
 DECEMBER 31
2020
 (In thousands, except share data)
ASSETS   
Cash and cash equivalents$87,507  $88,450 
Trade accounts receivable, net19,127  18,894 
Accounts receivable from affiliates6,377  4,764 
Inventories50,955  47,551 
Federal income tax receivable8,959 17,615 
Prepaid insurance4,184 2,564 
Other current assets15,274  8,308 
Total current assets192,383  188,146 
Property, plant and equipment, net189,369  172,417 
Intangibles, net32,534  35,330 
Investments in unconsolidated subsidiaries19,312  28,978 
Operating lease right-of-use assets9,235 10,324 
Other non-current assets46,085  40,984 
Total assets$488,918  $476,179 
LIABILITIES AND EQUITY   
Accounts payable$13,904  $5,522 
Accounts payable to affiliates562  125 
Revolving credit agreements  20,000 
Current maturities of long-term debt2,503  2,112 
Asset retirement obligations1,844  1,844 
Accrued payroll13,011  14,430 
Other current liabilities9,086  8,224 
Total current liabilities40,910  52,257 
Long-term debt14,501  24,353 
Operating lease liabilities10,109 11,196 
Asset retirement obligations41,693  39,888 
Pension and other postretirement obligations7,361  8,838 
Deferred income taxes12,563 17,550 
Liability for uncertain tax positions9,413  9,413 
Other long-term liabilities11,449  12,060 
Total liabilities147,999  175,555 
Stockholders' equity   
Common stock:   
Class A, par value $1 per share, 5,607,149 shares outstanding (December 31, 2020 - 5,489,615 shares outstanding)5,607  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)1,567  1,568 
Capital in excess of par value14,542  10,895 
Retained earnings330,373  294,270 
Accumulated other comprehensive loss(11,170) (11,599)
Total stockholders' equity340,919  300,624 
Total liabilities and equity$488,918  $476,179 

See notes to Unaudited Condensed Consolidated Financial Statements.
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NACCO INDUSTRIES, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

 THREE MONTHS ENDEDNINE MONTHS ENDED
 SEPTEMBER 30SEPTEMBER 30
2021 20202021 2020
 (In thousands, except per share data)
Revenues$51,742  $32,295 $142,743 $105,294 
Cost of sales37,413  25,475 111,737 89,553 
Gross profit14,329  6,820 31,006 15,741 
Earnings of unconsolidated operations17,652  15,145 46,536 44,926 
Contract termination settlement10,333 — 10,333 — 
Operating expenses
Selling, general and administrative expenses13,830  11,833 40,471 37,151 
Amortization of intangible assets902 734 2,795 2,303 
(Gain) loss on sale of assets
(10)— 17 (247)
14,722 12,567 43,283 39,207 
Operating profit27,592  9,398 44,592 21,460 
Other expense (income)   
Interest expense493  336 1,208 1,069 
Interest income(101)(95)(321)(625)
Closed mine obligations372  395 1,119 1,219 
Gain on equity securities(445)(35)(2,530)(351)
Other, net(161)(1,082)(418)(1,411)
 158  (481)(942)(99)
Income before income tax provision27,434  9,879 45,534 21,559 
Income tax provision2,597  1,857 5,231 1,321 
Net income$24,837  $8,022 $40,303 $20,238 
    
Earnings per share:
Basic earnings per share$3.47 $1.14 $5.65 $2.88 
Diluted earnings per share$3.47 $1.14 $5.63 $2.88 
    
Basic weighted average shares outstanding7,165  7,036 7,136 7,019 
Diluted weighted average shares outstanding7,165  7,036 7,153 7,035 

See notes to Unaudited Condensed Consolidated Financial Statements.
3

NACCO INDUSTRIES, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

 THREE MONTHS ENDEDNINE MONTHS ENDED
 SEPTEMBER 30SEPTEMBER 30
 2021 20202021 2020
 (In thousands)
Net income$24,837 $8,022 $40,303 $20,238 
Reclassification of pension and postretirement adjustments into earnings, net of $42 and $127 tax benefit in the three and nine months ended September 30, 2021, respectively, and net of $29 and $102 tax benefit in the three and nine months ended September 30, 2020, respectively.143 99 429 355 
Total other comprehensive income143 99 429 355 
Comprehensive income$24,980  $8,121 $40,732 $20,593 

See notes to Unaudited Condensed Consolidated Financial Statements.


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NACCO INDUSTRIES, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
 NINE MONTHS ENDED
 SEPTEMBER 30
 2021 2020
 (In thousands)
Operating activities   
Net cash provided by operating activities$67,794  $2,760 
Investing activities   
Expenditures for property, plant and equipment and acquisition of mineral interests(35,534) (19,802)
Proceeds from the sale of property, plant and equipment547 550 
Purchase of equity securities (2,000)
Other(52)72 
Net cash used for investing activities(35,039) (21,180)
    
Financing activities   
Additions to long-term debt3,633  6,199 
Reductions of long-term debt(3,131) (1,057)
Net reductions to revolving credit agreements(30,000) (7,000)
Cash dividends paid(4,200) (4,045)
Purchase of treasury shares (1,002)
Net cash used for financing activities(33,698) (6,905)
Cash and cash equivalents   
Total decrease for the period(943) (25,325)
Balance at the beginning of the period88,450  122,892 
Balance at the end of the period$87,507  $97,567 
See notes to Unaudited Condensed Consolidated Financial Statements.
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NACCO INDUSTRIES, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
 Class A Common StockClass B Common StockCapital in Excess of Par ValueRetained EarningsAccumulated Other Comprehensive Income (Loss)Total Stockholders' Equity
(In thousands, except per share data)
Balance, January 1, 2020$5,397 $1,569 $8,911 $284,852 $(11,337)$289,392 
Stock-based compensation88 — 377 — — 465 
Purchase of treasury shares(32)— (970)— — (1,002)
Net income— — — 6,166 — 6,166 
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— — — — 155 155 
Balance, March 31, 2020$5,453 $1,569 $8,318 $289,679 $(11,182)$293,837 
Stock-based compensation10 — 624 — — 634 
Net income— — — 6,050 — 6,050 
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— — — — 101 101 
Balance, June 30, 2020$5,463 $1,569 $8,942 $294,378 $(11,081)$299,271 
Stock-based compensation13 — 439 — — 452 
Conversion of Class B to Class A shares(1)— — — — 
Net income— — — 8,022 — 8,022 
Cash dividends on Class A and Class B common stock: $0.1925 per share— — — (1,355)— (1,355)
Reclassification adjustment to net income, net of tax— — — — 99 99 
Balance, September 30, 2020$5,477 $1,568 $9,381 $301,045 $(10,982)$306,489 
Balance, January 1, 2021$5,490 $1,568 $10,895 $294,270 $(11,599)$300,624 
Stock-based compensation92  923   1,015 
Conversion of Class B to Class A shares1 (1)    
Net income   8,961  8,961 
Cash dividends on Class A and Class B common stock: $0.1925 per share   (1,374) (1,374)
Reclassification adjustment to net income, net of tax    143 143 
Balance, March 31, 2021$5,583 $1,567 $11,818 $301,857 $(11,456)$309,369 
Stock-based compensation12  1,110   1,122 
Net income   6,505  6,505 
Cash dividends on Class A and Class B common stock: $0.1975 per share   (1,412) (1,412)
Reclassification adjustment to net income, net of tax    143 143 
Balance, June 30, 2021$5,595 $1,567 $12,928 $306,950 $(11,313)$315,727 
Stock-based compensation12  1,614   1,626 
Net income   24,837  24,837 
Cash dividends on Class A and Class B common stock: $0.1975 per share   (1,414) (1,414)
Reclassification adjustment to net income, net of tax    143 143 
Balance, September 30, 2021$5,607 $1,567 $14,542 $330,373 $(11,170)$340,919 

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 30, 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, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under 3 business segments: Coal Mining, North American Mining ("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® (Mitigation Resources) provides stream and wetland mitigation solutions.

The Company also has items not directly attributable to a reportable segment. Intercompany accounts and transactions are eliminated in consolidation. See Note 8 to the Unaudited Condensed Consolidated Financial Statements for further discussion of segment reporting.

The Company’s operating segments are further described below:

Coal Mining Segment
The Coal Mining segment, operating as The North American Coal Corporation® ("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 through September 30, 2021, on the Navajo Nation in New Mexico. Each mine is fully integrated with its customer's operations.

During the nine months ended September 30, 2021, the Company's operating coal mines were: Bisti Fuels Company, LLC (“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”).

Falkirk operates the Falkirk Mine in North Dakota. Falkirk is the sole supplier of lignite coal to the Coal Creek Station power plant pursuant to a contract under which Falkirk also supplies approximately 0.3 million tons of 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 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 closing of this sale is subject to the satisfaction of certain conditions and presently, the transaction is expected to close by the end of the first quarter of 2022. The timing could be accelerated, and the transaction could close before the end of 2021 if conditions are satisfied earlier than anticipated.

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 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 $5.0 million investment in Midwest AgEnergy, which operates two ethanol facilities in North Dakota.

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 supply 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
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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 an index which tracks broad measures of U.S. inflation.

Bisti supplied the Four Corners Power Plant through its contract mining agreement with the Navajo Transitional Energy Company ("NTEC"). This contract mining agreement was terminated effective September 30, 2021. As required under the agreement, NTEC paid the Company a termination fee of $10.3 million. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo Mine.

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 its intent 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 Leland Olds Station. The Synfuels Plant is a coal gasification plant, owned by Dakota Gasification Company (“Dakota Gas’), a subsidiary of Basin Electric, that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale.

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. Basin Electric indicated that if it decides to proceed with any changes that could reduce or eliminate the use of coal, the feedstock change is not expected to occur before 2026. On August 16, 2021, Bakken Energy (“Bakken”) and Basin Electric signed a non-binding term sheet to purchase the assets of Dakota Gas. Bakken stated the closing date is expected to be April 1, 2023. As part of the agreement between Basin Electric and Bakken, Basin Electric indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the satisfaction of specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with Bakken does not close.

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

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 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 Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. See Note 6 for further information on the Unconsolidated 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.

Caddo Creek Resources Company, LLC (“Caddo Creek”) ceased all mining and delivery of lignite and commenced mine reclamation in the fourth quarter of 2020. The financial results of Caddo Creek are consolidated within NACCO's financial statements for the nine months ended September 30, 2021. Prior to entering into reclamation, Caddo Creek met the definition of
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a VIE; therefore, the financial results of Caddo Creek are reported as Earnings of unconsolidated operations for the three and nine months ended September 30, 2020. The reclamation at Caddo Creek is expected to be substantially complete by June 30, 2022.

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 historically operated primarily at limestone quarries in Florida, but is focused on expanding outside of Florida, mining materials other than limestone and expanding the scope of mining operations provided to its customers. In the second quarter of 2021, NAMining entered into a one-year mining services contract with an existing customer for a sand and gravel quarry in Indiana. In the third quarter of 2021, NAMining entered into 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. In addition, NAMining will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada.

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

Minerals Management Segment
The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore, develop, mine, produce, market and sell gas, oil, and coal in exchange for royalty payments based on the lessees' sales of those minerals. During 2021 and 2020, the Minerals Management segment acquired mineral interests, primarily 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 payments 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 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 legacy royalty and mineral interests are located in Ohio (Utica and Marcellus shale natural gas), Louisiana (Haynesville shale and Cotton Valley formation natural gas), Texas (Cotton Valley and Austin Chalk formation natural gas), Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal and coalbed methane and natural gas) and North Dakota (coal, oil and natural gas). The majority of the Company’s legacy reserves were acquired as part of its historical coal mining operations. Specialized employees in the Minerals Management segment also provide surface and mineral acquisition and lease maintenance services related to Company operations.

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

The balance sheet at December 31, 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

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

The Minerals Management segment enters into 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 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 and are recognized over the primary term of the contract, which is generally five years.

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

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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 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 nine months ended September 30, 2021 and 2020, royalty income recognized in the reporting periods related to performance obligations satisfied in prior reporting periods was immaterial. During the third quarter of 2021, the Company recognized $1.8 million of variable consideration that was previously constrained due to uncertainty of collectability.

Disaggregation of Revenue
In accordance with ASC 606-10-50, the Company disaggregates revenue from contracts with customers into major goods and service lines and timing of transfer of goods and services. The Company determined that disaggregating revenue into these categories achieves the disclosure objective of depicting how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. The Company’s business consists of the Coal Mining, NAMining and Minerals Management segments as well as Unallocated Items. See Note 8 to the Unaudited Condensed Consolidated Financial Statements for further discussion of segment reporting.
THREE MONTHS ENDEDNINE MONTHS ENDED
SEPTEMBER 30SEPTEMBER 30
2021 20202021 2020
Timing of Revenue Recognition
Goods transferred at a point in time$20,436 $19,871 $61,931 $61,131 
Services transferred over time31,306 12,424 80,812 44,163 
Total revenues$51,742 $32,295 $142,743 $105,294 

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Contract Balances
The opening and closing balances of the Company’s current and long-term accounts receivable, contract assets and contract liabilities are as follows:
Contract balances
Trade accounts receivable, netContract asset
(long-term)
Contract liability (current)Contract liability (long-term)
Balance, January 1, 2021$18,894 $4,984 $941 $3,626 
Balance, September 30, 202119,127 5,790 824 3,683 
Increase (decrease)$233 $806 $(117)$57 

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.

The amount of revenue recognized in both of the three months ended September 30, 2021 and 2020 that was included in the opening contract liability was $0.2 million. The amount of revenue recognized in both of the nine months ended September 30, 2021 and 2020 that was included in the opening contract liability was $0.7 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 million in the remainder of 2021, $3.8 million in 2022, $0.3 million in 2023, and $0.1 million in 2024 related to the contract liability remaining at September 30, 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.

The Company has no 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
2021
 DECEMBER 31
2020
Coal$17,172 $17,695 
Mining supplies33,783 29,856 
 Total inventories$50,955  $47,551 

NOTE 4—Stockholders' Equity

Stock Repurchase Program: 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. 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 months ended September 30, 2020.

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 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
Quoted Prices inSignificant
Active Markets forSignificant OtherUnobservable
Identical AssetsObservable InputsInputs
DescriptionDate(Level 1)(Level 2)(Level 3)
September 30, 2021
Assets:
Equity securities$15,120 $15,120 $— $— 
$15,120 $15,120 $— $— 
December 31, 2020
Assets:
Equity securities$13,164 $13,164 $— $— 
$13,164 $13,164 $— $— 

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 less than $0.1 million and $1.0 million during the three and nine months ended September 30, 2021, respectively, and a gain of $0.5 million and $0.4 million in the three and nine months ended September 30, 2020, 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 gain of $0.4 million and $1.6 million during the three and nine months ended September 30, 2021, respectively, and a loss of $0.5 million and $0.1 million in the three and nine months ended September 30, 2020 related to the investment in these equity securities.

The gains and losses related to equity securities are reported on the line (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 nine months ended September 30, 2021 and 2020.

NOTE 6—Unconsolidated Subsidiaries

Each of the Company's wholly owned Unconsolidated Subsidiaries, within the Coal Mining and NAMining segments, meet the definition of a VIE. The Unconsolidated Subsidiaries are capitalized primarily with debt financing provided by or supported by their respective customers, and generally without recourse to NACCO and NACoal. 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 $19.3 million and $29.0 million at September 30, 2021 and December 31, 2020, respectively. The Company's maximum risk of loss relating to these entities is limited to its invested capital, which was $5.8 million and $6.5 million at September 30, 2021 and December 31, 2020,
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respectively. Earnings of unconsolidated operations were $17.7 million and $46.5 million during the three and nine months ended September 30, 2021, respectively, and $15.1 million and $44.9 million during the three and nine months ended September 30, 2020, respectively.

The contract mining agreement between Bisti and NTEC was terminated effective September 30, 2021. As required under the agreement, NTEC paid the Company a termination fee of $10.3 million. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo Mine.

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.

NOTE 7—Contingencies

Various legal and regulatory proceedings and claims have been or may be asserted against NACCO and certain subsidiaries relating to the conduct of their businesses. These proceedings and claims are incidental to the ordinary course of business of the Company. Management believes that it has meritorious defenses and will vigorously defend the Company in these actions. Any costs that management estimates will be paid as a result of these claims are accrued when the liability is considered probable and the amount can be reasonably estimated.  If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some circumstances, an estimate of the possible loss. 
These matters are subject to inherent uncertainties, and unfavorable rulings could occur. If an unfavorable ruling were to occur, there exists the possibility of an adverse impact on the Company’s financial position, results of operations and cash flows of the period in which the ruling occurs, or in future periods.

NOTE 8—Business Segments

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

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

All financial statement line items below operating profit (other income including interest expense and interest income, the provision for income taxes and net income) are presented and discussed within this Form 10-Q on a consolidated basis.
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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 ENDEDNINE MONTHS ENDED
 SEPTEMBER 30SEPTEMBER 30
 2021 20202021 2020
Revenues
Coal Mining$23,682  $20,395 $70,484 $62,896 
NAMining17,693  9,443 51,321 33,115 
Minerals Management10,607 2,722 21,715 9,950 
Unallocated Items1,594 904 2,647 1,257 
Eliminations(1,834)(1,169)(3,424)(1,924)
Total$51,742  $32,295 $142,743 $105,294 
Operating profit (loss)   
Coal Mining$23,121  $11,174 $40,347 $25,857 
NAMining312  244 1,225 1,519 
Minerals Management9,454 1,673 17,862 6,450 
Unallocated Items(5,170)(3,623)(14,738)(12,341)
Eliminations(125)(70)(104)(25)
Total$27,592  $9,398 $44,592 $21,460 
Expenditures for property, plant and equipment and acquisition of mineral interests
Coal Mining$5,646 $3,150 $10,378 $7,817 
NAMining13,309 3,220 19,127 10,406 
Minerals Management450 633 5,948 1,372 
Unallocated Items2 — 81 207 
Total$19,407  $7,003 $35,534 $19,802 
Depreciation, depletion and amortization
Coal Mining$4,323 $3,793 $12,657 $10,951 
NAMining1,014 723 2,843 2,021 
Minerals Management423 327 1,392 981 
Unallocated Items36 33 106 91 
Total$5,796 $4,876 $16,998 $14,044 

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Item 2. - Management's Discussion and Analysis of Financial Condition and Results of Operations
(Amounts in thousands, except as noted and per share data)

Management's Discussion and Analysis of Financial Condition and Results of Operations contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These statements are based upon management's current expectations and are subject to various uncertainties and changes in circumstances. Important factors that could cause actual results to differ materially from those described in these forward-looking statements are set forth below under the heading “Forward-Looking Statements."
Management's Discussion and Analysis of Financial Condition and Results of Operations include NACCO Industries, Inc.® (“NACCO”) and its wholly owned subsidiaries (collectively, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines for power generation companies 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® (“Mitigation Resources”) provides stream and wetland mitigation solutions.

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

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

The Company’s operating segments are further described below:

Coal Mining Segment
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 through September 30, 2021, on the Navajo Nation in New Mexico. Each mine is fully integrated with its customer's operations.

During the nine months ended September 30, 2021, the Company's operating coal mines were: Bisti Fuels Company, LLC (“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”).

Falkirk operates the Falkirk Mine in North Dakota. Falkirk is the sole supplier of lignite coal to the Coal Creek Station power plant pursuant to a contract under which Falkirk also supplies approximately 0.3 million tons of 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 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 closing of this sale is subject to the satisfaction of certain conditions and presently, the transaction is expected to close by the end of the first quarter of 2022. The timing could be accelerated, and the transaction could close before the end of 2021 if conditions are satisfied earlier than anticipated.

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 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 $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 supply 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 an index which tracks broad measures of U.S. inflation.

Bisti supplied the Four Corners Power Plant through its contract mining agreement with the Navajo Transitional Energy Company ("NTEC"). This contract mining agreement was terminated effective September 30, 2021. As required under the agreement, NTEC paid the Company a termination fee of $10.3 million. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo Mine.

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 its intent 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 Leland Olds Station. The Synfuels Plant is a coal gasification plant, owned by Dakota Gasification Company (“Dakota Gas’), a subsidiary of Basin Electric, that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale.

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. Basin Electric indicated that if it decides to proceed with any changes that could reduce or eliminate the use of coal, the feedstock change is not expected to occur before 2026. On August 16, 2021, Bakken Energy (“Bakken”) and Basin Electric signed a non-binding term sheet to purchase the assets of Dakota Gas. Bakken stated the closing date is expected to be April 1, 2023. As part of the agreement between Basin Electric and Bakken, Basin Electric indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the satisfaction of specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with Bakken does not close.

Coteau, Coyote, Falkirk, MLMC and Sabine supply lignite 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. MLMC’s coal supply contract contains a take or pay provision; all other coal supply contracts are requirements contracts under which earnings can fluctuate. Certain coal supply contracts can be terminated early, which would result in a reduction to future earnings.

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

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 VIEs is reported as Earnings of unconsolidated operations
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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 Unaudited Condensed Consolidated Statements of Operations includes income taxes related to these entities. See Note 6 for further information on the Unconsolidated 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, fluctuations in diesel fuel prices can result in significant fluctuations in earnings at MLMC.

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

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 in the fourth quarter of 2020. The reclamation at Caddo Creek is expected to be substantially complete by June 30, 2022. The terms of the contract to perform mine reclamation contain a fixed-price component and therefore, Caddo Creek no longer meets the VIE criteria. As a result, Caddo Creek is consolidated within the Company's financial statements.

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 historically operated primarily at limestone quarries in Florida, but is focused on expanding outside of Florida, mining materials other than limestone and expanding the scope of mining operations provided to its customers. In the second quarter of 2021, NAMining entered into a one-year mining services contract with an existing customer for a sand and gravel quarry in Indiana. In the third quarter of 2021, NAMining entered into 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. In addition, NAMining will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada.

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

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Minerals Management Segment
The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore, develop, mine, produce, market and sell gas, oil, and coal in exchange for royalty payments based on the lessees' sales of those minerals. During 2021 and 2020, the Minerals Management segment acquired mineral interests, primarily 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 payments 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 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 legacy royalty and mineral interests are located in Ohio (Utica and Marcellus shale natural gas), Louisiana (Haynesville shale and Cotton Valley formation natural gas), Texas (Cotton Valley and Austin Chalk formation natural gas), Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal, coalbed methane and natural gas) and North Dakota (coal, oil and natural gas). The majority of the Company’s legacy reserves were acquired as part of its historical coal mining operations.

The Minerals Management segment owns royalty interests, mineral interests, nonparticipating royalty interests, and overriding royalty interests. The Company may own more than one type of mineral and royalty interest in the same tract of land. For example, where the Company owns an overriding royalty interest in a lease on the same tract of land in which it owns a mineral interest, the overriding royalty interest in that tract will relate to the same gross acres as the mineral interest in that tract.

The Minerals Management segment will benefit from the continued development of its mineral properties without the need for investment of additional capital once mineral and royalty interests have been acquired. The Minerals Management segment does not 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 interests, the Company’s access to information concerning activity and operations of its royalty and mineral interests is limited. The Company does not have information that would be available to 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 39 through 41 in the Company's Annual Report on Form 10-K for the year ended December 31, 2020. The Company's Critical Accounting Policies and Estimates have not materially changed since December 31, 2020.

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CONSOLIDATED FINANCIAL SUMMARY

The results of operations for NACCO were as follows for the three and nine months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Revenues:
   Coal Mining$23,682 $20,395 $70,484 $62,896 
   NAMining17,693 9,443 51,321 33,115 
   Minerals Management10,607 2,722 21,715 9,950 
   Unallocated Items1,594 904 2,647 1,257 
   Eliminations(1,834)(1,169)(3,424)(1,924)
Total revenue$51,742  $32,295 $142,743 $105,294 
Operating profit (loss):
   Coal Mining (a)
$23,121 $11,174 $40,347 $25,857 
   NAMining312 244 1,225 1,519 
   Minerals Management9,454 1,673 17,862 6,450 
   Unallocated Items(5,170)(3,623)(14,738)(12,341)
   Eliminations(125)(70)(104)(25)
Total operating profit27,592  9,398 44,592 21,460 
   Interest expense493  336 1,208 1,069 
   Interest income(101)(95)(321)(625)
   Closed mine obligations372 395 1,119 1,219 
   Gain on equity securities(445)(35)(2,530)(351)
   Other, net(161)(1,082)(418)(1,411)
Other expense (income), net158  (481)(942)(99)
Income before income tax provision27,434 9,879 45,534 21,559 
Income tax provision2,597 1,857 5,231 1,321 
Net income$24,837 $8,022 $40,303 $20,238 
Effective income tax rate9.5 % 18.8 %11.5 % 6.1 %
(a) During the third quarter of 2021, NTEC paid the Company a $10.3 million contract termination fee.

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

Third Quarter of 2021 Compared with Third Quarter of 2020 and First Nine Months of 2021 Compared with First Nine Months of 2020

Other expense (income), net

Gain on equity securities represents changes in the market price of invested assets reported at fair value. The change in the third quarter of 2021 and the first nine months of 2021 compared with the respective 2020 periods was due to fluctuations in the market prices of the underlying assets. See Note 5 to the Unaudited Condensed Consolidated Financial Statements for further discussion of equity securities.

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 2020, the Company received a $1.0 million payment from NACC India's customer which has been reported on the line, Other, net.

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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 estimated annual effective income tax rate for the nine months ended September 30, 2021 reflects the impact of higher pre-tax income in 2021 compared with 2020, including the termination fee associated with the Bisti contract termination. The estimated annual effective income tax rate differs from the U.S. federal statutory rate due, in part, to the benefit from percentage 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 Biden administration has proposed changes that would eliminate certain U.S. federal income tax benefits currently available to coal mining and oil and gas exploration and development companies. Such proposed changes, as well as any increase in the U.S. income tax rate, could have a significant impact on the Company’s cash tax expenses and deferred taxes in future periods.

LIQUIDITY AND CAPITAL RESOURCES OF NACCO

Cash Flows

The following tables detail NACCO's changes in cash flow for the nine months ended September 30:
 2021 2020 Change
Operating activities:     
Net cash provided by operating activities$67,794  $2,760  $65,034 
Investing activities:     
Expenditures for property, plant and equipment and acquisition of mineral interests(35,534) (19,802) (15,732)
Other495 (1,378)1,873 
Net cash used for investing activities(35,039) (21,180) (13,859)
Cash flow before financing activities$32,755  $(18,420) $51,175 

The $65.0 million change in net cash provided by operating activities was primarily due to an increase in earnings, including the Bisti $10.3 million termination payment, and a net favorable change in working capital, including:
A reduction in Federal income tax receivable in the first nine months of 2021 compared with an increase in the first nine months of 2020, and
Decreased payments made under deferred compensation and long-term incentive compensation plans in the first nine months of 2021 compared with the first nine months of 2020.

The change in net cash used for investing activities was primarily attributable to an increase in expenditures for property, plant and equipment in the NAMining and Coal Mining segments and the acquisition of mineral interests within the Minerals Management segment.
 2021 2020 Change
Financing activities:     
Net reductions to long-term debt and revolving credit agreement$(29,498) $(1,858) $(27,640)
Cash dividends paid(4,200)(4,045)(155)
Purchase of treasury shares (1,002)1,002 
Net cash used for financing activities$(33,698) $(6,905) $(26,793)

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

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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. In addition, under the Company’s tax sharing agreement, subsidiaries make federal income tax payments to NACCO. NACCO makes payments to the IRS on behalf of the consolidated group.

NACoal has an unsecured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that expires in August 2022. There were no borrowings outstanding under the NACoal Facility at September 30, 2021. 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 30, 2021. At September 30, 2021, the excess availability under the NACoal Facility was $124.9 million, which reflects a reduction for outstanding letters of credit of $25.1 million.

The Company utilizes equipment financing debt to fund certain equipment purchases. As of September 30, 2021, the Company had $14.7 million in equipment debt financing outstanding.

The Company believes funds available from cash on hand, the NACoal Facility, equipment financing 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. The Company is in the process of refinancing the NACoal Facility. Based on the current status of the refinancing, the Company believes that it is probable that the NACoal Facility will be refinanced by December 31, 2021.

Surety Bonds

The Company uses surety bonds to guarantee performance of its consolidated mine reclamation obligations. During the nine months ended September 30, 2021, the Company provided a $15.0 million letter of credit to its surety company to collateralize a portion of its remaining surety bonds and the Company expects to provide another $5.0 million letter of credit to its surety company before the end of 2021. In addition, during the nine months ended September 30, 2021, the Company replaced $8.0 million of outstanding surety bonds with letters of credit. 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 $35.5 million during the first nine months of 2021. Planned expenditures for the remainder of 2021 are expected to be approximately $7 million in the Coal Mining segment and $1 million in the NAMining segment. Planned expenditures for 2022 are expected to be approximately $24 million in the NAMining segment, $19 million in the Coal Mining segment and $2 million at Mitigation Resources. The Minerals Management segment is evaluating additional investments in mineral and royalty interests of up to $15 million by the end of 2022.

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

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
2021
 DECEMBER 31
2020
 Change
Cash and cash equivalents$87,507  $88,450  $(943)
Other net tangible assets259,494  244,907  14,587 
Intangible assets, net32,534  35,330  (2,796)
Net assets379,535  368,687  10,848 
Total debt(17,004) (46,465) 29,461 
Bellaire closed mine obligations(21,612) (21,598) (14)
Total equity$340,919  $300,624  $40,295 
Debt to total capitalization5% 13% (8)%

The increase in other net tangible assets was primarily due to an increase in Property, plant and equipment and a decrease in Deferred income taxes, partially offset by a decrease in Federal incomes tax receivable at September 30, 2021 compared with December 31, 2020.

Contractual Obligations, Contingent Liabilities and Commitments

Since December 31, 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 46 in the Company's Annual Report on Form 10-K for the year ended December 31, 2020, except for the changes in the letters of credit as described under the Surety Bonds section in this Form 10-Q. See Note 6 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 months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Unconsolidated operations8,287  7,645 21,950  21,273 
Consolidated operations768  724 2,378  2,306 
Total tons delivered9,055  8,369 24,328  23,579 

The results of operations for the Coal Mining segment were as follows for the three and nine months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Revenues$23,682  $20,395 $70,484 $62,896 
Cost of sales19,651 16,379 60,905 57,514 
Gross profit4,031 4,016 9,579 5,382 
Earnings of unconsolidated operations(a)
16,615 14,277 43,411 42,104 
Contract termination settlement10,333 — 10,333 — 
Selling, general and administrative expenses6,960 6,385 20,152 19,326 
Amortization of intangible assets902 734 2,795 2,303 
(Gain) loss on sale of assets(4)— 29 — 
Operating profit$23,121  $11,174 $40,347 $25,857 

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

Third Quarter of 2021 Compared with Third Quarter of 2020

Revenues increased 16.1% in the third quarter of 2021 compared with the third quarter of 2020 primarily due to 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 quarter of 2021 compared with the third quarter of 2020:
 Operating Profit
2020$11,174 
Increase (decrease) from:
Contract termination settlement10,333 
Earnings of unconsolidated operations2,338 
Gross profit15 
Gain on sale of assets
Selling, general and administrative expenses(575)
Amortization of intangibles(168)
2021$23,121 

Operating profit increased $11.9 million in the third quarter of 2021 compared with the third quarter of 2020 primarily due to the $10.3 million payment related to the Bisti contract termination recognized during the third quarter of 2021 and an increase in the earnings of unconsolidated operations, partially offset by an increase in selling, general and administrative expenses.

The increase in earnings of unconsolidated operations was primarily due to contractual price escalation as well as an increase in customer demand at Coteau, Falkirk and Sabine. These increases were partially offset by the expected reduction in fees earned at Liberty as the scope of final reclamation activities declined.

Gross profit was comparable between periods as a decrease in the profit per ton delivered at MLMC was offset by earnings associated with the reclamation contract at Caddo Creek. In addition, the third quarter of 2020 included certain costs associated with the termination of the Camino Real Fuels, LLC contract mining agreement.

The increase in selling, general and administrative expenses was primarily due to higher insurance expense and an increase in employee-related costs. Included in insurance expense is an increase of $0.4 million that is reimbursed by one of the Unconsolidated Subsidiaries. The offsetting income related to the reimbursement is included in Earnings of unconsolidated operations.

First Nine Months of 2021 Compared with First Nine Months of 2020

Revenues increased 12.1% in the first nine months of 2021 compared with the first nine months of 2020 primarily due to the recognition of reclamation revenue from Caddo Creek.

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The following table identifies the components of change in operating profit for the first nine months of 2021 compared with the first nine months of 2020:
 Operating Profit
2020$25,857 
Increase (decrease) from:
Contract termination settlement10,333 
Gross profit4,197 
Earnings of unconsolidated operations1,307 
Selling, general and administrative expenses(826)
Amortization of intangibles(492)
Loss on sale of assets(29)
2021$40,347 

Operating profit increased $14.5 million in the first nine months of 2021 compared with the first nine months of 2020 primarily due to the payment related to the Bisti contract termination recognized during the third quarter of 2021, an increase in gross profit and an increase in earnings of unconsolidated operations. The improvement in gross profit was mainly due to income at Caddo Creek and a reduction in costs at Centennial.

The increase in earnings of unconsolidated operations was primarily due to contractual price escalation as well as an increase in customer demand at Falkirk and Sabine. The increase was partially offset by the expected reduction in fees earned at Liberty as the scope of final reclamation activities declined, the termination of the Camino Real Fuels, LLC contract mining agreement effective July 1, 2020 and the cessation of coal deliveries at Caddo Creek.

The increase in selling, general and administrative expenses was primarily due to higher insurance expense. Included in insurance expense is an increase of $1.0 million that is reimbursed by one of the Unconsolidated Subsidiaries. The offsetting income related to the reimbursement is included in Earnings of unconsolidated operations.

NORTH AMERICAN MINING ("NAMining") SEGMENT

FINANCIAL REVIEW
Tons delivered by the NAMining segment were as follows for the three and nine months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Unconsolidated operations2,735 2,359 7,602 6,841 
Consolidated operations11,398 9,213 32,640 28,099 
Total tons delivered14,133 11,572 40,242 34,940 

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The results of operations for the NAMining segment were as follows for the three and nine months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Total revenues$17,693  $9,443 $51,321 $33,115 
Reimbursable costs12,278 5,505 37,835 21,037 
Revenues excluding reimbursable costs$5,415 $3,938 $13,486 $12,078 
Total revenues$17,693 $9,443 $51,321 $33,115 
Cost of sales17,052 8,808 48,723 30,797 
Gross profit641 635 2,598 2,318 
Earnings of unconsolidated operations(a)
1,037 868 3,125 2,822 
Selling, general and administrative expenses1,372 1,259 4,510 3,868 
Gain on sale of assets(6)— (12)(247)
Operating profit$312  $244 $1,225  $1,519 

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

Total revenues increased 87.4% and 55.0% in the third quarter and first nine months of 2021 compared with the 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. The relocation of draglines related to new and amended contracts is the main driver of the increase in reimbursable costs. The increase in revenues excluding reimbursable costs is primarily due to an increase in tons delivered.

The following table identifies the components of change in operating profit for the third quarter of 2021 compared with the third quarter of 2020:
 Operating Profit
2020$244 
Increase (decrease) from:
Earnings of unconsolidated operations169 
Gross profit
Gain on sale of assets
Selling, general and administrative expenses(113)
2021$312 

Operating profit increased $0.1 million in the third quarter of 2021 compared with the third quarter of 2020. Increased tons delivered under existing contracts and contributions from new mining contracts were offset by an increase in operating expenses mainly due to higher employee-related costs, including medical costs, and higher business development expenses.

The following table identifies the components of change in operating profit for the first nine months of 2021 compared with the first nine months of 2020:
 Operating Profit
2020$1,519 
Increase (decrease) from:
Selling, general and administrative expenses(642)
Gain on sale of assets(235)
Earnings of unconsolidated operations303 
Gross profit280 
2021$1,225 

Operating profit decreased $0.3 million in the first nine months of 2021 compared with the first nine months of 2020 primarily due to an increase in selling, general and administrative expenses, mainly attributable to higher employee-related costs and an increase in business development expenses, partially offset by an increase in earnings of unconsolidated operations and an
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improvement in gross profit. The increase in both earnings of unconsolidated operations and gross profit was primarily due to 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 months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Revenues$10,607  $2,722 $21,715 $9,950 
Cost of sales755 537 2,398 1,793 
Gross profit9,852 2,185 19,317 8,157 
Selling, general and administrative expenses398 512 1,455 1,707 
Operating profit$9,454  $1,673 $17,862  $6,450 

Revenues and operating profit increased significantly in the three and nine months ended September 30, 2021 compared with the respective 2020 periods due in part to $3.3 million of settlement income recognized during the third quarter of 2021. In addition, the first nine months of 2021 included an increase in royalty income generated by gas production from the Ohio and Louisiana mineral interests, as well as oil production from the Permian Basin and Eagle Ford Shale mineral interests acquired in the fourth quarter of 2020 and early in the second quarter of 2021, respectively. Favorable changes in natural gas and oil prices also contributed to the improvement in revenues and operating profit. The decrease in selling, general and administrative expenses is primarily due to the absence of a $0.5 million charge taken in the second quarter of 2020 to write-off certain leasehold interests.

UNALLOCATED ITEMS AND ELIMINATIONS

FINANCIAL REVIEW

Unallocated Items and Eliminations were as follows for the three and nine months ended September 30:
THREE MONTHS NINE MONTHS
 2021 20202021 2020
Operating loss$(5,295) $(3,693)$(14,842)(12,366)

The operating loss increased in the three and nine months ended September 30, 2021 primarily due to higher employee-related costs and business development initiatives.

NACCO Industries, Inc. Outlook

Coal Mining Outlook - 2021
Coal deliveries for the fourth quarter of 2021 are expected to decrease compared with the fourth quarter of 2020 primarily as a result of the termination of the Bisti contract at the end of the 2021 third quarter and current expectations for customer requirements.

The Company expects operating profit for the Coal Mining segment to increase substantially over the prior year fourth quarter operating loss because the 2020 fourth quarter included a $2.0 million charge to write down MLMC's coal inventory and $2.6 million in expense for costs associated with a voluntary separation program and an asset impairment. Excluding the impact of these 2020 items, operating profit in the fourth quarter of 2021 is expected to decrease from the prior year fourth quarter. The decrease is primarily attributable to reduced earnings on lower deliveries at the unconsolidated Coal Mining operations and significantly lower results expected at MLMC due to higher costs, partly offset by lower operating expenses as a result of an anticipated decrease in employee-related costs and the absence of wind-down costs recognized in 2020 at Camino Real.

The anticipated reduction in fourth quarter earnings at the unconsolidated Coal Mining operations is expected to be mainly driven by the Bisti contract termination and a reduction in fees earned at Liberty, as the scope of final mine reclamation has declined since 2020. The decrease is expected to be partly offset by improved earnings due to contractual price escalation.
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Overall, full-year 2021 coal deliveries are expected to be moderately lower than 2020. Despite fewer deliveries, operating profit for the 2021 full year is expected to increase, even after excluding the impact of the $10.3 million termination payment in 2021 and the 2020 inventory write down and fixed asset impairment and voluntary separation charges, mainly as a result of income associated with performing mine reclamation at Caddo Creek, a reduction in expenses at Centennial and the absence of costs associated with the closure of Camino Real.

Full-year 2021 earnings at the unconsolidated Coal Mining operations are expected to be comparable to 2020 as increased earnings at Coteau, Falkirk and Sabine are expected to be offset by reduced fees earned at Liberty and a reduction in earnings from the Bisti and Camino Real contract terminations.

Excluding the termination payment received in 2021 and the fixed asset impairment charge of $1.1 million recognized in the 2020 fourth quarter, Segment adjusted EBITDA for the 2021 fourth quarter and full year is expected to increase over the respective prior year periods as a result of operating profit improvements and an increase in depreciation, depletion and amortization expense. The increase in depreciation, depletion and amortization expense is primarily due to higher capital expenditures at MLMC in years subsequent to 2018.

Capital expenditures are expected to be approximately $7 million in the fourth quarter of 2021 and approximately $17 million for the 2021 full year.

The Company's contract structure eliminates exposure to spot coal market price fluctuations. However, fluctuations in natural gas prices and the availability of renewable generation, particularly wind, can contribute to changes in power plant dispatch and customer demand for coal. The significant increase in natural gas prices in the third quarter of 2021 contributed to an increase in customer power plant dispatch and coal deliveries. Sustained higher natural gas prices could lead to increased demand for coal and positively affect Coal Mining segment results. Over the longer term, the Company continues to believe that customer demand will remain pressured by continuing increases in subsidized renewable generation sources, particularly wind. Future changes to expectations for customer power plant dispatch could affect the Company’s outlook.

Coal Mining Outlook - 2022
As previously announced, Great River Energy ("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 and its affiliates. The closing of this sale is subject to the satisfaction of certain conditions. Presently, closing is expected to occur in the first quarter of 2022; however, closing could occur before the end of 2021 if closing conditions are satisfied earlier than anticipated. Upon completion of the sale of Coal Creek Station, the existing agreements between GRE and Falkirk will terminate, and GRE will pay Falkirk $14.0 million. GRE will also transfer ownership of an office building located in Bismarck, North Dakota, and convey membership units in Midwest AgEnergy to another wholly owned and consolidated subsidiary of NACCO.

If GRE's sale to Rainbow Energy is 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 be paid a management fee per ton of coal delivered for operating the mine, 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.

In 2022, the Company expects coal deliveries to decrease from 2021 levels as a result of the Bisti contract termination and current expectations of customer requirements.

Excluding the Bisti and expected GRE termination payments, Coal Mining operating profit in 2022 is expected to decrease significantly compared with 2021. This decrease is primarily the result of expected significant reductions in earnings at the consolidated and unconsolidated Coal Mining operations, as well as an anticipated increase in operating expenses. The increase in operating expenses is primarily due to expected higher insurance costs.

Results at the consolidated mining operations are expected to decrease significantly in 2022 from 2021 primarily due to an increase in the cost per ton of coal delivered in 2022 compared with 2021 at MLMC. The increase in the cost per ton is partly attributable to increased diesel fuel costs and higher depreciation expense related to recent capital expenditures to develop a new mine area.

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The reduction in earnings at the unconsolidated Coal Mining operations is expected to be mainly driven by lower earnings at Falkirk. To support the transfer of Coal Creek Station, 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 an index which tracks a broad measure of U.S. inflation. Termination of the Bisti contract in late 2021 will also contribute to a decline in the earnings at the unconsolidated mining operations in 2022.

Segment adjusted EBITDA, excluding the termination payments of $10.3 million from NTEC and the anticipated $14 million from GRE, is expected to decrease significantly in 2022 from 2021 primarily as a result of the forecasted reduction in operating profit.

Capital expenditures are expected to be approximately $19 million in 2022. The elevated levels of capital expenditures in the Coal Mining segment expected through 2022 relate to the development of a new mine area at MLMC. The increase in capital expenditures associated with mine development will result in higher depreciation expense in future periods that will unfavorably affect future operating profit. Capital expenditures for MLMC are expected to return to lower pre-2019 levels in 2023.

Additional premature closures or reductions in dispatch of power plants served by the Company's mines would have a material adverse effect on the future 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 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 owned by Dakota Gas that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide and other chemical products for sale. In August 2021, Basin Electric signed a non-binding term sheet to sell the assets of Dakota Gas. As part of the agreement, Basin Electric indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the satisfaction of specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with the potential buyer does not close.

NAMining Outlook
NAMining expects tons delivered and operating profit to increase in the 2021 fourth quarter and full year over the respective prior year periods primarily as a result of increased production under existing contracts and contributions from mining contracts entered into during 2021, partially offset by an increase in operating expenses. In 2022, NAMining expects full-year operating profit to increase significantly over 2021 due to contributions from contracts entered into during 2021 and an expected increase in customer requirements. Segment adjusted EBITDA for the 2021 fourth quarter and full year, as well as in 2022, is expected to increase significantly compared with the respective prior year periods as a result of the improved operating profit and an increase in depreciation expense.

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 a larger dragline that will increase production capacity. Deliveries are expected to be approximately 1.5 million tons annually once mining commences with the larger dragline. The larger dragline is anticipated to be commissioned in 2023. NAMining also amended a contract with 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 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.

In the third quarter, 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.

NAMining anticipates that these new or revised contracts will be accretive to earnings in the 2021 fourth quarter and in 2022. 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.
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In 2019, NAMining's subsidiary, Sawtooth Mining, LLC, entered into a mining services agreement to serve as the exclusive contract miner for the Thacker Pass lithium project in northern Nevada, owned by Lithium Nevada Corp., a subsidiary of Lithium Americas Corp. (TSX: LAC) (NYSE: LAC). Lithium Americas owns the lithium reserves at Thacker Pass and will be responsible for the processing and sale of the lithium produced. In early October 2021, Lithium Americas provided an update on the Thacker Pass project, which noted that final permitting decisions are expected to be received in the first quarter of 2022. Early-works construction is expected to begin in the first half of 2022. At maturity, this management fee contract is expected to deliver fee income similar to a mid-sized management fee coal mine.

Capital expenditures are expected to be approximately $1 million and $20 million in the 2021 fourth quarter and full-year, respectively. In 2022, capital expenditures are expected to be approximately $24 million primarily for the acquisition, relocation and refurbishment of draglines, as well as the acquisition of other mining equipment to support the expansion of contract-mining services beyond NAMining's historical dragline-oriented model, including the acquisition of equipment to support the Thacker Pass lithium project. The cost of mining equipment related to Thacker Pass will be reimbursed by the customer over a seven-year period from the equipment acquisition date.

Minerals Management Outlook
The Minerals Management segment derives income from royalty-based leases under which lessees make payments to the Company based on their sale of natural gas, oil, natural gas liquids and coal, extracted primarily by third parties.

In 2020, Minerals Management took impairment charges of $0.6 million and $6.7 million in the second and fourth quarters, respectively, related to coal-related legacy assets. Excluding the 2020 fourth-quarter charge, operating profit and Segment adjusted EBITDA in the Minerals Management segment are expected to decrease in the 2021 fourth quarter primarily due to the natural production decline curve of certain newer wells in Ohio.

Full-year 2021 operating profit and Segment adjusted EBITDA are expected to increase over 2020, including and excluding the prior year impairment charge, due to the addition of royalty income generated from the recently acquired Permian Basin and Eagle Ford Shale mineral interests and higher oil and gas market prices.

Operating profit and Segment adjusted EBITDA in 2022 are expected to decrease significantly from 2021 primarily driven by reduced production due to the natural decline curve on wells in Ohio, expectations for lower natural gas and oil prices, and the absence of $3.3 million of settlement income recognized in 2021. The Company expects oil and gas market prices to moderate in 2022 and stabilize at levels consistent with expected full-year 2021 averages.

Commodity prices are inherently volatile. Natural gas and oil benchmark prices increased in the third quarter of 2021 when compared with earlier periods. If future natural gas and oil prices remain at higher levels than anticipated, results for the fourth quarter of 2021 and 2022 full year could be favorably impacted.

Minerals Management is evaluating additional investments in mineral and royalty interests of up to $15 million by the end of 2022. These investments are expected to be accretive, but each investment's contribution to earnings is dependent on the details of that investment, including the size and type of interests acquired and the stage and timing of mineral development. The contribution of each investment could also vary due to commodity price changes. These acquired interests are expected to align with the Company’s strategy of selectively acquiring mineral and royalty interests with a balance of near-term cash-flow yields and long-term growth potential, in high-quality reservoirs offering diversification from the Company’s legacy mineral interests.

Consolidated Outlook
Overall, NACCO expects a significant increase in consolidated operating profit, net income and Consolidated Adjusted EBITDA in the fourth quarter of 2021 over 2020, primarily due to the absence of prior year charges totaling $11.6 million. Excluding these items, fourth quarter 2021 consolidated operating profit is expected to decrease from the prior year primarily due to anticipated lower results in the Coal Mining and Minerals Management segments partially offset by an increase in the NAMining segment.

The Company expects net income for the 2021 full year to be significantly higher than 2020, resulting from the Bisti
termination payment and the absence of the prior-year charges totaling $12.1 million. Excluding these items, the Company also expects significantly higher 2021 net income and Consolidated Adjusted EBITDA as a result of the strong results in the first nine months of the year. The anticipated effective income tax rate is expected to be between 11% and 14% in 2021.

In 2022, NACCO expects consolidated net income to decrease significantly from 2021. Lower earnings in the Coal Mining segment and an anticipated reduction in earnings in the Minerals Management segment are expected to be partially offset by
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lower income tax expense. Securing contracts for new mining projects and acquisitions of additional mineral interests could be accretive to the current forecast.

The Company expects significant cash flow before financing activities in 2021 compared to a substantial use of cash in 2020. Consolidated capital expenditures are expected to be between $44 million and $49 million in 2021 and $55 million to $60 million in 2022. Capital expenditures in 2022 include approximately $2 million for expenditures at Mitigation Resources of North America®. As a result of the forecasted capital expenditures and anticipated decrease in net income, cash flow before financing activities in 2022 is expected to return to a significant use of cash.

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 COVID-19 variants, the effectiveness of actions taken to contain and 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 operations have not been 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.

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

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 mining skills to expand the range of contract mining services it provides. NAMining advanced these efforts in the first nine months of 2021 when it entered into a contract to mine sand and gravel in Indiana and 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 in Texas and Arkansas 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, dragline-oriented limestone mining business and expand its geographic footprint 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, but the pace of growth will be dependent on the mix and scale of new projects.

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 a market and price environment that the Company believes remains well-aligned with its strategy and objectives. The Minerals Management segment will benefit from the continued development of its mineral properties without additional capital investment, as all further development costs are borne entirely by third-party producers who lease the minerals. This business model can deliver higher average operating margins over the life of a reserve than traditional oil and gas companies that bear the cost of exploration, production and/or development. Catapult, the Company’s business unit focused on managing and expanding the Company’s portfolio of oil and gas mineral and royalty interests, has developed a strong network to source and secure new acquisitions, and has several potential acquisitions under review. The goal is to construct a diversified portfolio of high-quality oil and 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 an 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.
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The Company also continues to pursue activities which can strengthen the resiliency of its existing coal mining operations. The Company remains focused on managing coal production costs and maximizing efficiencies and operating capacity at mine locations to help customers with management fee contracts be more competitive. These activities benefit both customers and the Company's Coal Mining segment, as fuel cost is a significant driver for power plant dispatch. Increased power plant dispatch results in increased demand for coal by the Coal Mining segment's customers. Fluctuating natural gas prices and availability of renewable energy sources, such as wind and solar, could affect the amount of electricity dispatched from coal-fired power plants.

The Company continues to look for opportunities to expand its coal mining business 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 very limited in the current environment. 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.    

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

FORWARD-LOOKING STATEMENTS

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

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

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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 quarter of 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 30, 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, 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 1 to 31, 2021)
— $— — $22,659,516 
Month #2
(August 1 to 31, 2021)
— $— — $22,659,516 
Month #3
(September 1 to 30, 2021)
— $— — $22,659,516 
     Total— $— — $22,659,516 

(1)    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 4 to the Unaudited Condensed Consolidated Financial Statements for further discussion of the Company's stock repurchase program.
    
Item 3    Defaults Upon Senior Securities
    None.

Item 4    Mine Safety Disclosures
Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 filed with this Quarterly Report on Form 10-Q for the period ended September 30, 2021.

Item 5    Other Information
    None.

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Item 6    Exhibits
Exhibit  
Number* Description of Exhibits
31(i)(1) 
31(i)(2) 
32 
95 
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
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
*    Numbered in accordance with Item 601 of Regulation S-K.




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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 3, 2021/s/ Elizabeth I. Loveman 
 Elizabeth I. Loveman 
 Vice President and Controller
(principal financial and accounting officer)
 
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