NACCO Industries (NC) 10-K15 Mar 232022 FY Annual reportFinancial data

Company Profile

Cover Page

Cover Page - USD ($)	12 Months Ended
Cover Page - USD ($)	Dec. 31, 2022	Mar. 03, 2023	Jun. 30, 2022
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-9172
Entity Registrant Name	NACCO INDUSTRIES, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	34-1505819
Entity Address, Address Line One	5875 Landerbrook Drive,
Entity Address, Address Line Two	Suite 220
Entity Address, City or Town	Cleveland,
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	44124-4069
City Area Code	440
Local Phone Number	229-5151
Title of 12(b) Security	Class A Common Stock, $1 par value per share
Trading Symbol	NC
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 159,988,559
Documents Incorporated by Reference	Portions of the Company's Proxy Statement for its 2023 annual meeting of stockholders are incorporated herein by reference in Part III of this Form 10-K.
Entity Central Index Key	0000789933
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Amendment Flag	false
Shares Outstanding Class A
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		5,936,134
Shares Outstanding Class B
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		1,565,929

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2022
Auditor Information [Abstract]
Auditor Firm ID	42
Auditor Name	Ernst & Young LLP
Auditor Location	Cleveland, Ohio

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Income Statement [Abstract]
Revenues	$ 241,719	$ 191,846
Cost of sales	173,877	148,394
Gross profit	67,842	43,452
Earnings of unconsolidated operations	57,250	60,843
Contract termination settlement	14,000	10,333
Operating expenses
Selling, general and administrative expenses	63,911	55,722
Amortization of intangible assets	3,719	3,556
Gain on sale of assets	(2,463)	(60)
Asset impairment charges	3,939	0
Operating expenses	69,106	59,218
Operating profit	69,986	55,410
Other (income) expense
Interest expense	2,034	1,719
Interest income	(1,449)	(449)
Closed mine obligations	1,179	1,297
Loss (gain) on equity securities	283	(3,423)
Income from equity method investee	(2,194)	0
Other contract termination settlements	(16,882)	0
Other, net	(708)	(584)
Other (income) expense	(17,737)	(1,440)
Income before income tax provision	87,723	56,850
Income tax provision	13,565	8,725
Net income	$ 74,158	$ 48,125
Earnings per share:
Basic earnings per share (in dollars per share)	$ 10.14	$ 6.73
Diluted earnings per share (in dollars per share)	$ 10.06	$ 6.69
Basic weighted average shares outstanding (in shares)	7,312	7,146
Diluted weighted average shares outstanding (in shares)	7,373	7,190

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net income	$ 74,158	$ 48,125
Other comprehensive income
Current period pension and postretirement plan adjustment, net of $363 tax benefit and $864 tax expense in 2022 and 2021, respectively	(1,310)	2,851
Reclassification of pension and postretirement adjustments into earnings, net of $140 and $170 tax benefit in 2022 and 2021, respectively	473	572
Total other comprehensive (loss) income	(837)	3,423
Comprehensive income	$ 73,321	$ 51,548

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Current period pension and postretirement plan adjustment, tax (benefit) expense	$ (363)	$ 864
Reclassification of pension and post retirement adjustments into earnings, tax benefit	$ (140)	$ (170)

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current assets
Cash and cash equivalents	$ 110,748	$ 86,005
Trade accounts receivable	37,940	25,667
Accounts receivable from affiliates	6,638	5,605
Inventories	71,488	54,085
Federal income tax receivable	15,687	15,054
Prepaid insurance	1,999	2,016
Other current assets	15,907	14,621
Total current assets	260,407	203,053
Property, plant and equipment, net	217,952	193,167
Intangibles, net	28,055	31,774
Investment in unconsolidated subsidiaries	14,927	19,090
Operating lease right-of-use assets	6,419	8,911
Other non-current assets	40,312	51,225
Total assets	568,072	507,220
Current liabilities
Accounts payable	11,952	12,208
Accounts payable to affiliates	1,362	741
Current maturities of long-term debt	3,649	2,527
Asset retirement obligations	1,746	1,820
Accrued payroll	18,105	16,339
Deferred revenue	833	4,082
Other current liabilities	6,623	8,299
Total current liabilities	44,270	46,016
Long-term debt	16,019	18,183
Operating lease liabilities	7,528	9,733
Asset retirement obligations	44,256	42,131
Pension and other postretirement obligations	5,082	6,605
Deferred income taxes	6,122	14,792
Liability for uncertain tax positions	9,329	10,113
Other long-term liabilities	8,500	7,531
Total liabilities	141,106	155,104
Common stock:
Capital in excess of par value	23,706	16,331
Retained earnings	404,924	336,778
Accumulated other comprehensive loss	(9,013)	(8,176)
Total stockholders’ equity	426,966	352,116
Total liabilities and equity	568,072	507,220
Class A Common Stock
Common stock:
Common stock	5,783	5,616
Class B Common Stock
Common stock:
Common stock	$ 1,566	$ 1,567

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical)	Dec. 31, 2022 $ / shares shares	Dec. 31, 2021 $ / shares shares
Class A Common Stock
Common stock, par value (USD per share) \| $ / shares	$ 1	$ 1
Common stock, shares outstanding (in shares) \| shares	5,782,944	5,616,568
Class B Common Stock
Common stock, par value (USD per share) \| $ / shares	$ 1	$ 1
Common stock, shares outstanding (in shares) \| shares	1,566,129	1,566,613
Common stock, convertible conversion ratio	1	1

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Operating Activities
Net income	$ 74,158	$ 48,125
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	26,816	23,085
Amortization of deferred financing fees	446	326
Deferred income taxes	(8,471)	(3,553)
Stock-based compensation	7,541	5,561
Gain on sale of assets	(2,463)	(60)
Contract termination settlement	(15,552)	0
Asset impairment charges	3,939	0
Other	(791)	1,647
Working capital changes:
Affiliates receivable/payable	0	495
Accounts receivable	(13,224)	(13,685)
Inventories	(6,834)	(6,534)
Other current assets	1,308	3,320
Accounts payable	252	7,445
Income taxes receivable/payable	(416)	2,699
Other current liabilities	1,026	6,004
Net cash provided by operating activities	67,735	74,875
Investing Activities
Expenditures for property, plant and equipment	(42,523)	(39,230)
Acquisition of mineral interests	(11,924)	(5,331)
Proceeds from the sale of assets	2,837	633
Proceeds from the sale of private company equity units	18,628	0
Other	(170)	(219)
Net cash used for investing activities	(33,152)	(44,147)
Financing Activities
Net reductions to revolving credit agreement	(4,000)	(26,000)
Additions to long-term debt	3,091	3,634
Reductions to long-term debt	(2,919)	(3,435)
Cash dividends paid	(6,012)	(5,617)
Other	0	(1,755)
Net cash used for financing activities	(9,840)	(33,173)
Cash and Cash Equivalents
Total increase (decrease) for the year	24,743	(2,445)
Balance at the beginning of the year	86,005	88,450
Balance at the end of the year	$ 110,748	$ 86,005

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands	Total	Common Stock Class A Common Stock	Common Stock Class B Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive (Loss) Income
Balance, beginning of period at Dec. 31, 2020	$ 300,624	$ 5,490	$ 1,568	$ 10,895	$ 294,270	$ (11,599)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation	5,561	125		5,436
Conversion of Class B to Class A shares	0	1	(1)
Net income	48,125				48,125
Cash dividends on Class A and Class B common stock	(5,617)				(5,617)
Current period other comprehensive income, net of tax	2,851					2,851
Reclassification adjustment to net income, net of tax	572					572
Balance, end of period at Dec. 31, 2021	352,116	5,616	1,567	16,331	336,778	(8,176)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation	7,541	166		7,375
Conversion of Class B to Class A shares	0	1	(1)
Net income	74,158				74,158
Cash dividends on Class A and Class B common stock	(6,012)				(6,012)
Current period other comprehensive income, net of tax	(1,310)					(1,310)
Reclassification adjustment to net income, net of tax	473					473
Balance, end of period at Dec. 31, 2022	$ 426,966	$ 5,783	$ 1,566	$ 23,706	$ 404,924	$ (9,013)

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in dollars per share) (USD per share)	$ 0.8200	$ 0.7850

Principles of Consolidation and

Principles of Consolidation and Nature of Operations	12 Months Ended
Principles of Consolidation and Nature of Operations	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation and Nature of Operations	Principles of Consolidation and Nature of Operations The Consolidated Financial Statements include the accounts of NACCO Industries, Inc. ® (“NACCO”) and its wholly owned subsidiaries (collectively, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines for power generation companies. The NAMining segment is a trusted mining partner for producers of aggregates, activated carbon, lithium and other industrial minerals. The Minerals Management segment, which includes the Catapult Mineral Partners (“Catapult”) business, acquires and promotes the development of mineral interests. Mitigation Resources of North America ® (“Mitigation Resources”) provides stream and wetland mitigation solutions. The Company also has items not directly attributable to a reportable segment. Intercompany accounts and transactions are eliminated in consolidation. See Note 15 to the 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 pursuant to a service-based business model. Coal is surface mined in North Dakota, Texas, Mississippi and through September 30, 2021, on the Navajo Nation in New Mexico. Each mine is fully integrated with its customer's operations. As of December 31, 2022, the Company's operating coal mines were: The Coteau Properties Company (“Coteau”), Coyote Creek Mining Company, LLC (“Coyote Creek”), The Falkirk Mining Company (“Falkirk”), Mississippi Lignite Mining Company (“MLMC”) and The Sabine Mining Company (“Sabine”). MLMC is the exclusive supplier of lignite to the Red Hills Power Plant in Ackerman, Mississippi. Choctaw Generation Limited Partnership ("CGLP") leases the Red Hills Power Plant from a Southern Company subsidiary pursuant to a leveraged lease arrangement. CGLP's ability to make required payments to the Southern Company subsidiary is dependent on the operational performance of the Red Hills Power Plant. During 2020, Southern Company revised the estimated cash flows to be received under the leveraged lease which resulted in a full impairment of the lease investment. If lease payments are not paid in full, the Southern Company subsidiary may be unable to make its corresponding payment to the holders of the underlying non-recourse debt related to the Red Hills Power Plant. Failure to make the required payment to the debtholders could represent an event of default that would give the debtholders the right to foreclose on, and take ownership of, the Red Hills Power Plant from the Southern Company subsidiary. On October 27, 2022, Southern Company disclosed in its Form 10-Q that it provided notice to the lessee, CGLP, to terminate the related operating and maintenance agreement effective June 30, 2023. CGLP failed to make the semi-annual lease payment due December 15, 2022. As a result, the Southern Company subsidiary was unable to make its corresponding payment to the debtholders. The parties to the lease agreement are currently negotiating a potential restructuring, which could result in rescission of the termination notice. The parties to the lease have entered into a forbearance agreement which suspends the related contractual rights of the parties while they continue restructuring negotiations. The ultimate outcome of this matter cannot be determined at this time but could have a material impact on the Company's financial statements if the operating and maintenance agreement is terminated. On May 2, 2022, Great River Energy (“GRE”) completed the sale of Coal Creek Station and the adjacent high-voltage direct current transmission line to Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. As a result of the completion of the sale of Coal Creek Station, the Coal Sales Agreement, the Mortgage and Security Agreement and the Option Agreement between GRE and Falkirk were terminated. The Coal Sales Agreement (“CSA”) between Falkirk and Rainbow Energy became effective upon the closing of the transaction. Falkirk continues to supply all coal requirements of Coal Creek Station and is paid a management fee per ton of coal delivered. To support the transfer to new ownership, Falkirk agreed to a reduction in the current per ton management fee from the effective date of the CSA through May 31, 2024. After May 31, 2024, the per ton management fee increases to a higher base in line with 2021 fee levels, and thereafter adjusts annually according to an index which tracks broad measures of U.S. inflation. Rainbow Energy is responsible for funding all mine operating costs, including mine reclamation, and directly or indirectly providing all of the capital required to operate the mine. The initial production period is expected to run through May 1, 2032, but the CSA may be extended or terminated early under certain circumstances. The Company recognized a gain of $30.9 million within the accompanying Condensed Consolidated Statements of Operations during the second quarter of 2022 as GRE paid NACoal $14.0 million in cash, as well as transferred ownership of an office building with an estimated fair value of $4.1 million, and conveyed membership units in Midwest AgEnergy Group, LLC (“MAG”), a North Dakota-based ethanol business, with an estimated fair value of $12.8 million, as agreed to under the termination and release of claims agreement between Falkirk and GRE. Prior to receiving the membership units from GRE, the Company held a $5.0 million investment in the same privately-held company carried at cost, less impairment. Subsequent to the receipt of the additional membership units, the Company began to account for the investment under the equity method of accounting. During the third quarter, the Company recorded $2.2 million, which represented its share of MAG's earnings on the "Income from equity method investee" line within the accompanying Consolidated Statements of Operations. On December 1, 2022, HLCP Ethanol Holdco, LLC (“HLCP”) completed its acquisition of MAG. Upon closing of the transaction, NACCO transferred its ownership interest in MAG to HLCP and received a cash payment of $18.6 million and recognized a $1.3 million loss during the fourth quarter of 2022 on the line "Other, net" within the accompanying Consolidated Statements of Operations. The HLCP acquisition agreement includes two contingent earn-out arrangements under which additional payments are possible. The first earn-out is based on the achievement of EBITDA targets through December 31, 2024. The second earn-out is based on the development of a carbon dioxide pipeline that will support a carbon dioxide sequestration project over a four-year period commencing on the transaction closing date. Additional payments to NACCO could range from $0 to approximately $13.6 million based on achievement of the two earn-outs as well as payment of amounts held in escrow. Any future payments associated with the earn-outs or amounts held in escrow will be recognized when realized, consistent with the accounting for gain contingencies. 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. AEP intends to retire the Pirkey Plant during March 2023. Sabine expects deliveries to cease in March 2023 and final reclamation to begin on April 1, 2023. Funding for mine reclamation is the responsibility of SWEPCO, and Sabine will receive compensation for providing mine reclamation services. The contract mining agreement between Bisti Fuels Company, LLC (“Bisti”) and its customer, Navajo Transitional Energy Company ("NTEC") was terminated effective September 30, 2021. As required under the agreement, NTEC paid the Company a termination fee of $10.3 million reported on the line Contract termination settlement on the Consolidated Statements of Operations. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo Mine. 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 16 for further discussion of Coyote Creek's guarantees. All operating coal mines other than MLMC meet the definition of a 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 Consolidated Statements of Operations, and the Company’s investment is reported on the line Investments in unconsolidated subsidiaries in the 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 Consolidated Statements of Operations includes income taxes related to these entities. See Note 16 for further information on the Unconsolidated Subsidiaries. While Falkirk meets the definition of a VIE, the completion of the Rainbow Energy transaction resulted in a VIE reconsideration event. As the terms of the CSA between Falkirk and Rainbow Energy are substantially the same as the terms of the coal supply contract between Falkirk and GRE, Falkirk remains a VIE and Rainbow Energy is the primary beneficiary; therefore, NACCO will continue to account for Falkirk under the equity method. The Company performs contemporaneous reclamation activities at each mine in the normal course of operations. Under all of the Unconsolidated Subsidiaries’ contracts, the customer has the obligation to fund final mine reclamation activities. Under certain contracts, the Unconsolidated Subsidiary holds the mine permit and is therefore responsible for final mine reclamation activities. To the extent the Unconsolidated Subsidiary performs such final reclamation, it is compensated for providing those services in addition to receiving reimbursement from customers for costs incurred. The MLMC contract is the only operating coal contract in which the Company is responsible for all operating costs, capital requirements and final mine reclamation; therefore, MLMC is consolidated within NACCO’s financial statements. MLMC sells coal to its customer at a contractually agreed-upon price which adjusts monthly, primarily based on changes in the level of established indices which reflect general U.S. inflation rates. Profitability at MLMC is affected by customer demand for coal and changes in the indices that determine sales price and actual costs incurred. As diesel fuel is heavily weighted among the indices used to determine the coal sales price, fluctuations in diesel fuel prices can result in significant fluctuations in earnings at MLMC. MLMC delivers coal to the Red Hills Power Plant in Ackerman, Mississippi. The Red Hills Power Plant supplies electricity to the Tennessee Valley Authority ("TVA") under a long-term Power Purchase Agreement ("PPA"). 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. NAMining Segment The NAMining segment provides value-added contract mining and other services for producers of industrial minerals. The segment is a platform for the Company’s growth and diversification of mining activities outside of the thermal coal industry. NAMining provides contract mining services for independently owned mines and quarries, creating value for its customers by performing the mining aspects of its customers’ operations. This allows customers to focus on their areas of expertise: materials handling and processing, product sales and distribution. 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. As of December 31, 2022, NAMining operates mines in Florida, Texas, Arkansas, Indiana, Virginia and Nebraska and will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada. Certain of the entities within the NAMining segment are VIEs and are accounted for under the equity method as Unconsolidated Subsidiaries. See Note 16 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. The Minerals Management segment owns royalty interests, mineral interests, nonparticipating royalty interests and overriding royalty interests. • Royalty Interest. Royalty interests generally result when the owner of a mineral interest leases the underlying minerals to an exploration and production company pursuant to an oil and gas lease. Typically, the resulting royalty interest is a cost-free percentage of production revenues for minerals extracted from the acreage. A holder of royalty interests is generally not responsible for capital expenditures or lease operating expenses, but royalty interests may be calculated net of post-production expenses, and typically has no environmental liability. Royalty interests leased to producers expire upon the expiration of the oil and gas lease and revert to the mineral owner. • Mineral Interest. Mineral interests are perpetual rights of the owner to explore, develop, exploit, mine and/or produce any or all of the minerals lying below the surface of the property. The holder of a mineral interest has the right to lease the minerals to an exploration and production company. Upon the execution of an oil and gas lease, the lessee (the exploration and production company) becomes the working interest owner and the lessor (the mineral interest owner) has a royalty interest. • Non-Participating Royalty Interest (“NPRIs”). NPRI is an interest in oil and gas production which is created from the mineral estate. The NPRI is expense-free, bearing no operational costs of production. The term “non-participating” indicates that the interest owner does not share in the bonus, rentals from a lease, nor the right to participate in the execution of oil and gas leases. The NPRI owner does; however, typically receive royalty payments. • Overriding Royalty Interest (“ORRIs”). ORRIs are created by carving out the right to receive royalties from a working interest. Like royalty interests, ORRIs do not confer an obligation to make capital expenditures or pay for lease operating expenses and have limited environmental liability; however, ORRIs may be calculated net of post-production expenses, depending on how the ORRI is structured. ORRIs that are carved out of working interests are linked to the same underlying oil and gas lease that created the working interest, and therefore, such ORRIs are typically subject to expiration upon the expiration or termination of the oil and gas lease. 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 ORRI in a lease on the same tract of land in which it owns a mineral interest, the ORRI in that tract will relate to the same gross acres as the mineral interest in that tract. The Minerals Management segment will benefit from the continued development of its mineral properties without the need for investment of additional capital once mineral and royalty interests have been acquired. The Minerals Management segment does not currently have any material investments under which it would be required to bear the cost of exploration, production or development. Total consideration for the 2022 and 2021 acquisitions of mineral and royalty interests was $11.9 million and $5.3 million, respectively. The 2022 acquisitions included 13.6 thousand gross acres and 880 net royalty acres. The 2021 acquisitions included 20.6 thousand gross acres and 1.8 thousand net royalty acres. Total mineral and royalty interests included approximately 141.4 thousand gross acres and 60.8 thousand net royalty acres at December 31, 2022. See Note 18 for further discussion of Minerals Management.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
Significant Accounting Policies	Dec. 31, 2022
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies Use of Estimates: The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and judgments. These estimates and judgments affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities (if any) at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Cash and Cash Equivalents: Cash and cash equivalents include cash in banks and highly liquid investments with original maturities of three months or less. Property, Plant and Equipment, Net: Property, plant and equipment are initially recorded at cost. Depreciation, depletion and amortization are provided in amounts sufficient to amortize the cost of the assets, including assets recorded under finance leases, over their estimated useful lives using the straight-line method or the units-of-production method. Buildings and building improvements are depreciated over the life of the mine, which is generally 30 years. Estimated lives for machinery and equipment range from three Royalty Interests in Oil and Natural Gas Properties: The Company follows the successful efforts method of accounting for its royalty and mineral interests. Under this method, costs to acquire mineral and royalty interests in oil and natural gas properties are capitalized when incurred. Acquisitions of royalty interests of oil and natural gas properties are considered asset acquisitions and are recorded at cost. As an owner of mineral and royalty interests and not working interests, the Company is not required to make capital expenditures and did not make capital expenditures to convert proved undeveloped reserves from undeveloped to developed. Acquisition costs of proved royalty and mineral interests are amortized using the units of production method over the life of the property, which is estimated using proved reserves. For purposes of amortization, interests in oil and natural gas properties are grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic condition. The Company reviews and evaluates its royalty interests in oil and natural gas properties for impairment when events or changes in circumstances indicate that the related carrying amounts may not be recoverable. Proved oil and gas properties are reviewed for impairment when events and circumstances indicate a potential decline in the fair value of such properties below the carrying value, such as a downward revision of the reserve estimates or lower commodity prices. When such events or changes in circumstances occur, the Company estimates the undiscounted future cash flows expected in connection with the properties and compares such future cash flows to the carrying amounts of the properties to determine if the carrying amounts are recoverable. If the carrying value of the properties is determined to not be recoverable based on the undiscounted cash flows, an impairment charge is recognized by comparing the carrying value to the estimated fair value of the properties. See Note 18 for further discussion of the Company's royalty and mineral interests. Long-Lived Assets: The Company periodically evaluates long-lived assets for impairment when changes in circumstances or the occurrence of certain events indicate the carrying amount of an asset or asset group may not be recoverable. Upon identification of indicators of impairment, the Company evaluates the carrying value of the asset by comparing the estimated future undiscounted cash flows generated from the use of the asset or asset group and its eventual disposition with the asset's net carrying value. If the carrying value of an asset is considered impaired, an impairment charge is recorded for the amount that the carrying value of the long-lived asset or asset group exceeds its fair value. Fair value is estimated as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. See Note 9 for further discussion of the Company's nonrecurring fair value measurements. At MLMC, the costs of mining operations are not reimbursed by MLMC's customer. As such, increased costs at MLMC or decreased revenues could materially reduce the Company's profitability. Any reduction in customer demand at MLMC, including reductions related to reduced mechanical availability of the customer’s power plant, would adversely affect the Company's operating results and could result in significant impairments. MLMC has approximately $125 million of long-lived assets, including property, plant and equipment and its coal supply agreement intangible asset, which are subject to periodic impairment analyses and review. Identifying and assessing whether impairment indicators exist, or if events or changes in circumstances have occurred, including assumptions about future power plant dispatch levels, changes in future sales price, operating costs and other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual future operating results could differ significantly from these estimates, which may result in an impairment charge in a future period, which could have a substantial impact on the Company’s results of operations. Self-insurance Liabilities: The Company is generally self-insured for medical claims, certain workers’ compensation claims and certain closed mine liabilities. An estimated provision for claims reported and for claims incurred but not yet reported under the self-insurance programs is recorded and revised periodically based on industry trends, historical experience and management judgment. In addition, industry trends are considered within management's judgment for valuing claims. Changes in assumptions for such matters as legal judgments and settlements, inflation rates, medical costs and actual experience could cause estimates to change in the near term. Revenue Recognition: See Note 3 to the Consolidated Financial Statements for discussion of revenue recognition. Stock Compensation: The Company maintains long-term incentive programs that allow for the grant of shares of Class A common stock, subject to restrictions, as a means of retaining and rewarding selected employees for long-term performance and to increase ownership in the Company. Shares awarded under the plans are fully vested and entitle the stockholder to all rights of common stock ownership except that shares may not be assigned, pledged or otherwise transferred during the restriction period. In general, for shares awarded for years ended December 31, 2022 and December 31, 2021, the restriction period ends at the earliest of (i) three years after the participant's retirement date, (ii) three five The Company also has a stock compensation plan for non-employee directors of the Company under which a portion of the annual retainer for each non-employee director is paid in restricted shares of Class A common stock. For the year ended December 31, 2022, $110,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $175,000 ($250,000 for the Chairman) was paid in restricted shares of Class A common stock. For the year ended December 31, 2021, $105,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $167,000 ($250,000 for the Chairman) was paid in restricted shares of Class A common stock. Shares awarded under the plan are fully vested and entitle the stockholder to all rights of common stock ownership except that shares may not be assigned, pledged, hypothecated or otherwise transferred during the restriction period. In general, the restriction period ends at the earliest of (i) ten years from the award date, (ii) the date of the director's death or permanent disability, (iii) five years (or earlier with the approval of the Board of Directors) after the director's date of retirement from the Board of Directors, (iv) the date the director has both retired from the Board of Directors and has reached age 70, or (v) at such other time as determined by the Board of Directors in its sole and absolute discretion. Pursuant to this plan, the Company issued 30,034 and 45,223 shares related to the years ended December 31, 2022 and 2021, respectively. In addition to the mandatory retainer fee received in restricted stock, directors may elect to receive shares of Class A common stock in lieu of cash for up to 100% of the balance of their annual retainer, committee retainer and any committee chairman's fees. These voluntary shares are not subject to any restrictions. Total shares issued under voluntary elections were 480 in 2022 and 753 in 2021. After the issuance of these shares, there were 136,047 shares of Class A common stock available for issuance under this plan. Compensation expense related to these awards was $1.3 million ($1.0 million net of tax) and $1.3 million ($1.1 million net of tax) for the years ended December 31, 2022 and 2021, respectively. Compensation expense represents fair value based on the market price of the shares of Class A common stock at the grant date. Financial Instruments: Financial instruments held by the Company include cash and cash equivalents, accounts receivable, equity securities, accounts payable, revolving credit agreements and long-term debt. Fair Value Measurements: The Company accounts for the fair value measurement of its financial assets and liabilities in accordance with U.S. generally accepted accounting principles, which defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy requires an entity to maximize the use of observable inputs, where available, and minimize the use of unobservable inputs when measuring fair value. Described below are the three levels of inputs that may be used to measure fair value: Level 1 - Quoted prices in active markets that are accessible at the measurement date for identical assets or liabilities. Level 2 - Observable prices that are based on inputs not quoted on active markets, but corroborated by market data. Level 3 - Unobservable inputs are used when little or no market data is available. The hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. The classification of fair value measurements within the hierarchy is based upon the lowest level of input that is significant to the measurement. See Note 9 for further discussion of fair value measurements.

Revenue Recognition

Revenue Recognition	12 Months Ended
Revenue Recognition	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition Nature of Performance Obligations At contract inception, the Company assesses the goods and services promised in its contracts with customers and identifies a performance obligation for each promised good or service that is distinct. To identify the performance obligations, the Company considers all of the goods or services promised in the contract regardless of whether they are explicitly stated or are implied by customary business practices. Each mine or mine area has a contract with its respective customer that represents a contract under ASC 606. For its consolidated entities, the Company’s performance obligations vary by contract and consist of the following: At MLMC, each MMBtu delivered during the production period is considered a separate performance obligation. Revenue is recognized at the point in time that control of each MMBtu of lignite transfers to the customer. Fluctuations in revenue from period to period generally result from changes in customer demand. 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. Included within NAMining, Caddo Creek has a fixed-price contract to perform mine reclamation. The management service to perform mine reclamation is the performance obligation accounted for as a series. Performance momentarily creates an asset that the customer simultaneously receives and consumes; therefore, control is transferred to the customer over time. Revenue from this contract 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. 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 three Mitigation Resources generates and sells stream and wetland mitigation credits (known as mitigation banking) and provides services to those engaged in permittee-responsible stream and wetland mitigation. Each mitigation credit sale is considered a separate performance obligation. Revenue is recognized at the point in time that control of each mitigation credit transfers to the customer. Fluctuations in revenue from period to period generally result from changes in customer demand. Under the permittee-responsible stream and wetland mitigation model, the contracts are generally structured as a management fee agreement under which Mitigation Resources is reimbursed for all costs incurred in performing the required mitigation plus an agreed profit percentage or a fixed fee. The mitigation services provided is the performance obligation and is accounted for as a series. Performance momentarily creates an asset that the customer simultaneously receives and consumes; therefore, control is transferred to the customer as work is completed. Consistent with the conclusion that the customer simultaneously receives and consumes the benefits provided, an input-based measure of progress is appropriate. As each month of service is completed, revenue is recognized for the amount of actual costs incurred, plus the management fee or fixed fee. Fluctuations in revenue from period to period result from changes in customer demand primarily due to increases and decreases in activity levels of individual contracts and variances in reimbursable costs. Significant Judgments The Company’s contracts with its customers contain different types of variable consideration including, but not limited to, management fees that adjust based on volumes or MMBtu delivered, however, the terms of these variable payments relate specifically to the Company's efforts to satisfy one or more, but not all of, the performance obligations (or to a specific outcome from satisfying the performance obligations) in the contract. Therefore, the Company allocates each variable payment (and subsequent changes to that payment) entirely to the specific performance obligation to which it relates. Management fees, as well as general and administrative fees, are also adjusted based on changes in specified indices (e.g., CPI) to compensate for general inflation changes. Index adjustments, if applicable, are effective prospectively. Recognition of revenue and recognition of profit related to the Caddo Creek contract requires the use of assumptions and estimates related to the total contract value, the total cost at completion, and the measurement of progress towards completion of the performance obligation. Due to the nature of the contract, developing the estimated total contract value and total cost at completion requires the use of significant judgment. The total contract value includes variable consideration. The Company includes variable consideration in the transaction price at the most likely amount to be earned, based upon the Company’s assessment of expected performance. The Company records these amounts only to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved. Cost Reimbursement Certain contracts include reimbursement from customers of actual costs incurred for the purchase of supplies, equipment and services in accordance with contractual terms. Such reimbursable revenue is variable and subject to uncertainty, as the amounts received and timing thereof is highly dependent on factors outside of the Company’s control. Accordingly, reimbursable revenue is fully constrained and not recognized until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of a customer. The Company is considered a principal in such transactions and records the associated revenue at the gross amount billed to the customer with the related costs recorded as an expense within cost of sales. Prior Period Performance Obligations The Company records royalty income in the month production is delivered to the purchaser. As a mineral owner the Company has limited visibility into when new wells start producing and production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, the Company is required to estimate the amount of production delivered to the purchaser of the product and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded in "Trade accounts receivable" in the accompanying 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. During 2022, royalty income of $2.1 million was recognized for a settlement related to the Company's ownership interest in certain mineral rights. During 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 15 to the Consolidated Financial Statements for further discussion of segment reporting. The following table disaggregates revenue by major sources for the years ended December 31: Major Goods/Service Lines 2022 2021 Coal Mining $ 95,204 $ 82,831 NAMining 85,664 78,944 Minerals Management 60,242 31,003 Unallocated Items 2,952 4,695 Eliminations (2,343) (5,627) Total revenues $ 241,719 $ 191,846 Timing of Revenue Recognition Goods transferred at a point in time $ 92,842 $ 80,515 Services transferred over time 148,877 111,331 Total revenues $ 241,719 $ 191,846 Contract Balances The opening and closing balances of the Company’s current and long-term contract assets and liabilities and receivables are as follows: Contract balances Trade accounts receivable Contract asset Contract asset Contract liability (current) Contract liability (long-term) Balance at January 1, 2022 $ 25,667 $ — $ 5,985 $ 4,082 $ 1,453 Balance at December 31, 2022 37,940 409 5,985 833 1,709 Increase (decrease) $ 12,273 $ 409 $ — $ (3,249) $ 256 As described above, the Company enters into royalty contracts that grant exclusive right, title, and interest in and to minerals. The transaction price consists of a variable sales-based royalty and, in certain arrangements, a fixed component in the form of an up-front lease bonus payment. The timing of the payment of the fixed portion of the transaction price is upfront, however, the performance obligation is satisfied over the primary term of the contract, which is generally three three The Company expects to recognize $0.8 million in 2023, $1.5 million in 2024, $0.2 million in 2025, and de minimis amounts in 2026 and 2027 related to the contract liability remaining at December 31, 2022. The difference between the opening and closing balances of the Company’s contract balances results from the timing difference between the Company’s performance and the customer’s payment. The Company has no contract assets recognized from the costs to obtain or fulfill a contract with a customer.

Inventories

Inventories	12 Months Ended
Inventories	Dec. 31, 2022
Inventory Disclosure [Abstract]
Inventories	Inventories Inventories are summarized as follows: December 31 2022 2021 Coal $ 27,927 $ 19,352 Mining supplies 43,561 34,733 Total inventories $ 71,488 $ 54,085

Property, Plant and Equipment,

Property, Plant and Equipment, Net	12 Months Ended
Property, Plant and Equipment, Net	Dec. 31, 2022
Property, Plant and Equipment, Net [Abstract]
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net Property, plant and equipment, net includes the following: December 31 2022 2021 Coal lands and real estate $ 60,277 $ 52,011 Mineral interests 31,436 19,512 Plant and equipment 290,511 264,110 Property, plant and equipment, at cost 382,224 335,633 Less allowances for depreciation, depletion and amortization 164,272 142,466 $ 217,952 $ 193,167

Intangible Assets

Intangible Assets	12 Months Ended
Intangible Assets	Dec. 31, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets	Intangible Assets The Company has a coal supply agreement intangible asset which is subject to amortization based on units of production over the term of the lignite sales agreement which expires in 2032. The gross and net balances are set forth in the following table: Gross Carrying Accumulated Net Balance at December 31, 2022 Coal supply agreement $ 84,200 $ (56,145) $ 28,055 Balance at December 31, 2021 Coal supply agreement $ 84,200 $ (52,426) $ 31,774 Amortization expense for intangible assets was $3.7 million and $3.6 million in 2022 and 2021, respectively. Expected annual amortization expense of the coal supply agreement is $3.2 million in 2023, $3.1 million in 2024 and $3.0 million in 2025 through 2027.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company’s obligations associated with the retirement of long-lived assets are recognized at fair value at the time the legal obligations are incurred. Upon initial recognition of a liability, a corresponding amount is capitalized as part of the carrying value of the related long-lived asset and is depreciated either by the straight-line method or the units-of-production method. The liability is accreted each period until the liability is settled, at which time the liability is removed. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The Company's asset retirement obligations are principally for costs to close its surface mines and reclaim the land it has disturbed as a result of its normal mining activities as well as for costs to dismantle certain mining equipment at the end of the life of the mine. Management’s estimate involves a high degree of subjectivity. In particular, the obligation’s fair value is determined using a discounted cash flow technique and is based upon mining permit requirements and various assumptions including credit adjusted risk-free-rates, estimates of disturbed acreage, life of the mine, estimated reclamation costs, the application of various environmental laws and regulation and assumptions regarding equipment productivity. The Company reviews its asset retirement obligations at each mine site at least annually and makes necessary adjustments for permit changes and for revisions of estimates of the timing and extent of reclamation activities and cost estimates. The accretion of the liability is being recognized over the estimated life of each individual asset retirement obligation and is recorded in the line Cost of sales in the accompanying Consolidated Statements of Operations. The associated asset is recorded in Property, Plant and Equipment, net in the accompanying Consolidated Balance Sheets. The depreciation of the asset is recorded in the line Cost of sales in the accompanying Consolidated Statements of Operations. A reconciliation of the Company's beginning and ending aggregate carrying amount of the asset retirement obligations are as follows: Coal Mining Unallocated Items NACCO Balance at January 1, 2021 $ 25,040 $ 16,692 $ 41,732 Liabilities settled during the period (184) (869) (1,053) Accretion expense 1,996 1,304 3,300 Revision of estimated cash flows 46 (74) (28) Balance at December 31, 2021 $ 26,898 $ 17,053 $ 43,951 Liabilities settled during the period (223) (956) (1,179) Accretion expense 2,190 1,332 3,522 Revision of estimated cash flows (405) 113 (292) Balance at December 31, 2022 $ 28,460 $ 17,542 $ 46,002 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. These legacy liabilities include obligations for water treatment and other environmental remediation that arose as part of the normal course of closing these underground mining operations. Since Bellaire's properties are no longer active operations, no associated asset has been capitalized.

Current and Long-Term Financing

Current and Long-Term Financing	12 Months Ended
Current and Long-Term Financing	Dec. 31, 2022
Debt Disclosure [Abstract]
Current and Long-Term Financing	Current and Long-Term Financing Financing arrangements are obtained and maintained at the subsidiary level. NACCO has not guaranteed any borrowings of its subsidiaries. The following table summarizes the Company's available and outstanding borrowings: December 31 2022 2021 Total outstanding borrowings of NACoal: Revolving credit agreement $ — $ 4,000 Other debt 19,668 16,710 Total debt outstanding $ 19,668 $ 20,710 Current portion of borrowings outstanding $ 3,649 $ 2,527 Long-term portion of borrowings outstanding 16,019 18,183 $ 19,668 $ 20,710 Total available borrowings, net of limitations, under revolving credit agreement $ 116,285 $ 120,231 Unused revolving credit agreement $ 116,285 $ 116,231 Weighted average stated interest rate on total borrowings 3.9 % 3.7 % Annual maturities of total debt, excluding leases, are as follows: 2023 2,873 2024 2,497 2025 1,620 2026 5,955 2027 236 Thereafter 5,692 $ 18,873 Interest paid on total debt was $2.0 million and $1.6 million during 2022 and 2021, respectively. Deferred financing fees of $1.8 million were capitalized during 2021. NACoal has a secured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that was refinanced during 2021 and expires in November 2025. There were no borrowings outstanding under the NACoal Facility at December 31, 2022. At December 31, 2022, the excess availability under the NACoal Facility was $116.3 million, which reflects a reduction for outstanding letters of credit of $33.7 million. The NACoal Facility has performance-based pricing, which sets interest rates based upon NACoal achieving various levels of debt to EBITDA ratios, as defined in the NACoal Facility. Borrowings bear interest at a floating rate plus a margin based on the level of debt to EBITDA ratio achieved. The applicable margins, effective December 31, 2022, for base rate and LIBOR loans were 1.23% and 2.23%, respectively. The NACoal Facility has a commitment fee which is based upon achieving various levels of debt to EBITDA ratios. The commitment fee was 0.34% on the unused commitment at December 31, 2022. During the year ended December 31, 2022, the average borrowing under the NACoal Facility was $2.0 million. The weighted-average annual interest rate, including the floating rate margin, was 2.54% and 4.50% at December 31, 2022 and December 31, 2021, respectively. The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum net debt to EBITDA ratio of 2.75 to 1.00 and an interest coverage ratio of not less than 4.00 to 1.00. The NACoal Facility provides the ability to make loans, dividends and advances to NACCO, with some restrictions based on maintaining a maximum debt to EBITDA ratio of 1.50 to 1.00, or if greater than 1.50 to 1.00, a Fixed Charge Coverage Ratio of 1.10 to 1.00, in conjunction with maintaining unused availability thresholds of borrowing capacity, as defined in the NACoal Facility, of $15.0 million. At December 31, 2022, NACoal was in compliance with all financial covenants in the NACoal Facility. The obligations under the NACoal Facility are guaranteed by certain of NACoal's direct and indirect, existing and future domestic subsidiaries, and is secured by certain assets of NACoal and the guarantors, subject to customary exceptions and limitations. NACoal has a demand note payable to Coteau, one of the unconsolidated subsidiaries, which bears interest based on the applicable quarterly federal short-term interest rate as announced from time to time by the Internal Revenue Service. At December 31, 2022 and 2021, the balance of the note was $5.7 million and $2.6 million and the interest rate was 3.36% and 0.18%, respectively. NACoal has seven notes payable that are secured by twelve specified units of equipment, bear interest at a weighted average rate of 4.11%, and expire at various dates through 2027. One note includes a principal payment of $4.4 million at the end of the term on December 15, 2026. At December 31, 2022 and 2021, the outstanding balances of the notes were $13.2 million and $13.8 million, respectively.

Fair Value Disclosure

Fair Value Disclosure	12 Months Ended
Fair Value Disclosure	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Disclosure	Fair Value Disclosure Recurring Fair Value Measurements : The following table presents the Company's assets accounted for at fair value on a recurring basis: Fair Value Measurements at Reporting Date Using Quoted Prices in Significant Active Markets for Significant Other Unobservable Identical Assets Observable Inputs Inputs Description December 31, 2022 (Level 1) (Level 2) (Level 3) Assets: Equity securities $ 15,534 $ 15,534 $ — $ — $ 15,534 $ 15,534 $ — $ — Fair Value Measurements at Reporting Date Using Quoted Prices in Significant Active Markets for Significant Other Unobservable Identical Assets Observable Inputs Inputs Description December 31, 2021 (Level 1) (Level 2) (Level 3) Assets: Equity securities $ 16,070 $ 16,070 $ — $ — $ 16,070 $ 16,070 $ — $ — Bellaire's Mine Water Treatment Trust invests in available for sale 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 Mine Water Treatment Trust realized a loss of $2.2 million and a gain of $1.7 million in the years ended December 31, 2022 and 2021, respectively. See Note 7 for further discussion of Bellaire's Mine Water Treatment Trust. Prior to 2021, 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 $1.9 million and $1.7 million in the years ended December 31, 2022 and 2021, related to the investment in these equity securities. The change in fair value of equity securities is reported on the line Loss (gain) on equity securities in the Other (income) expense section of the Consolidated Statements of Operations. There were no transfers into or out of Levels 1, 2 or 3 during the year ended December 31, 2022. Nonrecurring Fair Value Measurements: The Company recorded the estimated fair value of an office building during the second quarter of 2022. In determining the $4.1 million fair value of the office building, the Company engaged an independent real estate appraiser to appraise the property utilizing observed sales transactions for similar assets as well as consideration of an income approach; therefore, it is classified as Level 2 within the fair value hierarchy. The office building is included in Property, plant and equipment, net in the accompanying Consolidated Balance Sheets. The Company regularly performs reviews of potential future development projects and identified certain legacy assets where future development is unlikely. As a result, the Company estimated the fair value of the assets using unobservable inputs, which are classified as Level 3 inputs. The long-lived assets, which included land, prepaid royalties and capitalized leasehold costs, were written off to zero in the third quarter of 2022 and resulted in non-cash asset impairment charges of $3.9 million in the Minerals Management segment. The impairment charges are reported on the line Asset impairment charges in the Consolidated Statements of Operations. Other Fair Value Measurement Disclosures: The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term maturities of these instruments. The fair values of revolving credit agreements and long-term debt, excluding finance leases, were determined using current rates offered for similar obligations taking into account subsidiary credit risk, which is Level 2 as defined in the fair value hierarchy. The fair value and the book value of revolving credit agreements and long-term debt, excluding finance leases, was $18.1 million and $18.9 million, respectively, at December 31, 2022 and $20.5 million and $20.4 million, respectively, at December 31, 2021. Financial instruments that potentially subject the Company to concentration of credit risk consist principally of accounts receivable. Under its mining contracts, the Company recognizes revenue and a related receivable as coal or other aggregates are delivered or predevelopment services are provided. These mining contracts provide for monthly settlements. The Company's significant credit concentration is uncollateralized; however, historically minimal credit losses have been incurred. To further reduce credit risk associated with accounts receivable, the Company performs periodic credit evaluations of its customers, but does not generally require advance payments or collateral.

Leases

Leases	12 Months Ended
Leases	Dec. 31, 2022
Leases [Abstract]
Leases	Leases The Company recognizes right-of-use assets (“ROU assets”) and lease liabilities for operating leases of real estate, mining and other equipment that expire at various dates through 2032. The majority of the Company's leases are operating leases. NACCO does not recognize leases with a term of 12 months or less on the balance sheet. Instead, the Company recognizes the related lease expense on a straight-line basis over the lease term. The Company accounts for lease and non-lease components as a single lease component. The Company's lease agreements do not contain lease payments that depend on an index or a rate, as such, minimum lease payments do not include variable lease payments. Leased assets and liabilities include the following at December 31: Description Location 2022 2021 Assets Operating Operating lease right-of-use assets $ 6,419 $ 8,911 Finance Property, plant and equipment, net (a) 843 334 Liabilities Current Operating Other current liabilities $ 1,039 $ 1,463 Finance Current maturities of long-term debt 776 150 Non-current Operating Operating lease liabilities $ 7,528 $ 9,733 Finance Long-term debt 19 190 (a) Finance leased assets are recorded net of accumulated amortization of $0.2 million and $0.3 million as of December 31, 2022 and December 31, 2021, respectively. The components of lease expense for the years ended December 31 are as follows: Description Location 2022 2021 Lease expense Operating lease cost Selling, general and administrative expenses $ 1,881 $ 2,122 Finance lease cost: Amortization of leased assets Cost of sales 128 220 Interest on lease liabilities Interest expense 13 31 Variable lease expense Selling, general and administrative expenses 534 571 Short-term lease expense Selling, general and administrative expenses 3,434 1,176 Total lease expense $ 5,990 $ 4,120 Future minimum finance and operating lease payments were as follows at December 31, 2022: Finance Leases Operating Leases Total 2023 $ 778 $ 1,599 $ 2,377 2024 12 1,474 1,486 2025 7 1,283 1,290 2026 — 1,314 1,314 2027 — 1,345 1,345 Subsequent to 2027 — 4,177 4,177 Total minimum lease payments 797 11,192 $ 11,989 Amounts representing interest 2 2,625 Present value of net minimum lease payments $ 795 $ 8,567 As most of the Company's leases do not provide an implicit rate, the Company determines the incremental borrowing rate based on the information available at the lease commencement date in determining the present value of lease payments. The Company considers its credit rating and the current economic environment in determining this collateralized rate. The assumptions used in accounting for ASC 842 for the years ended December 31 are as follows: 2022 2021 Weighted average remaining lease term (years) Operating 7.66 8.38 Finance 1.41 2.44 Weighted average discount rate Operating 7.13 % 7.08 % Finance 3.11 % 4.16 % The following table details cash paid for amounts included in the measurement of lease liabilities for the years ended December 31: 2022 2021 Operating cash flows from operating leases $ 2,097 $ 2,260 Operating cash flows from finance leases 13 31 Financing cash flows from finance leases 183 275
Leases	Leases The Company recognizes right-of-use assets (“ROU assets”) and lease liabilities for operating leases of real estate, mining and other equipment that expire at various dates through 2032. The majority of the Company's leases are operating leases. NACCO does not recognize leases with a term of 12 months or less on the balance sheet. Instead, the Company recognizes the related lease expense on a straight-line basis over the lease term. The Company accounts for lease and non-lease components as a single lease component. The Company's lease agreements do not contain lease payments that depend on an index or a rate, as such, minimum lease payments do not include variable lease payments. Leased assets and liabilities include the following at December 31: Description Location 2022 2021 Assets Operating Operating lease right-of-use assets $ 6,419 $ 8,911 Finance Property, plant and equipment, net (a) 843 334 Liabilities Current Operating Other current liabilities $ 1,039 $ 1,463 Finance Current maturities of long-term debt 776 150 Non-current Operating Operating lease liabilities $ 7,528 $ 9,733 Finance Long-term debt 19 190 (a) Finance leased assets are recorded net of accumulated amortization of $0.2 million and $0.3 million as of December 31, 2022 and December 31, 2021, respectively. The components of lease expense for the years ended December 31 are as follows: Description Location 2022 2021 Lease expense Operating lease cost Selling, general and administrative expenses $ 1,881 $ 2,122 Finance lease cost: Amortization of leased assets Cost of sales 128 220 Interest on lease liabilities Interest expense 13 31 Variable lease expense Selling, general and administrative expenses 534 571 Short-term lease expense Selling, general and administrative expenses 3,434 1,176 Total lease expense $ 5,990 $ 4,120 Future minimum finance and operating lease payments were as follows at December 31, 2022: Finance Leases Operating Leases Total 2023 $ 778 $ 1,599 $ 2,377 2024 12 1,474 1,486 2025 7 1,283 1,290 2026 — 1,314 1,314 2027 — 1,345 1,345 Subsequent to 2027 — 4,177 4,177 Total minimum lease payments 797 11,192 $ 11,989 Amounts representing interest 2 2,625 Present value of net minimum lease payments $ 795 $ 8,567 As most of the Company's leases do not provide an implicit rate, the Company determines the incremental borrowing rate based on the information available at the lease commencement date in determining the present value of lease payments. The Company considers its credit rating and the current economic environment in determining this collateralized rate. The assumptions used in accounting for ASC 842 for the years ended December 31 are as follows: 2022 2021 Weighted average remaining lease term (years) Operating 7.66 8.38 Finance 1.41 2.44 Weighted average discount rate Operating 7.13 % 7.08 % Finance 3.11 % 4.16 % The following table details cash paid for amounts included in the measurement of lease liabilities for the years ended December 31: 2022 2021 Operating cash flows from operating leases $ 2,097 $ 2,260 Operating cash flows from finance leases 13 31 Financing cash flows from finance leases 183 275

Contingencies

Contingencies	12 Months Ended
Contingencies	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Contingencies	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.

Stockholders' Equity and Earnin

Stockholders' Equity and Earnings Per Share	12 Months Ended
Stockholders' Equity and Earnings Per Share	Dec. 31, 2022
Equity [Abstract]
Stockholders' Equity and Earnings Per Share	Stockholders' Equity and Earnings Per Share NACCO Industries, Inc. Class A common stock is traded on the New York Stock Exchange under the ticker symbol “NC.” Because of transfer restrictions on Class B common stock, no trading market has developed, or is expected to develop, for the Company's Class B common stock. The Class B common stock is convertible into Class A common stock on a one-for-one basis at any time at the request of the holder. The Company's Class A common stock and Class B common stock have the same cash dividend rights per share. As the liquidation and dividend rights are identical, any distribution of earnings would be allocated to Class A and Class B stockholders on a proportionate basis, and accordingly the net income per share for each class of common stock is identical. The Class A common stock has one vote per share and the Class B common stock has ten votes per share. The total number of authorized shares of Class A common stock and Class B common stock at December 31, 2022 was 25,000,000 shares and 6,756,176 shares, respectively. Treasury shares of Class A common stock totaling 2,434,769 and 2,600,661 at December 31, 2022 and 2021, respectively, have been deducted from shares outstanding. Stock Repurchase Program: On November 10, 2021, the Company's Board of Directors approved a stock purchase program ("2021 Stock Repurchase Program") providing for the purchase of up to $20.0 million of the Company’s outstanding Class A common stock through December 31, 2023. The timing and amount of any repurchases under the 2021 Stock Repurchase Program are determined at the discretion of the Company's management based on a number of factors, including the availability of capital, other capital allocation alternatives, market conditions for the Company's Class A common stock and other legal and contractual restrictions. The 2021 Stock Repurchase Program does not require the Company to acquire any specific number of shares and may be modified, suspended, extended or terminated by the Company without prior notice and may be executed through open market purchases, privately negotiated transactions or otherwise. All or part of the repurchases under the 2021 Stock Repurchase Program may be implemented under a Rule 10b5-1 trading plan, which would allow repurchases under pre-set terms at times when the Company might otherwise be restricted from doing so under applicable securities laws. There were no stock repurchases in 2022 or 2021 under the 2021 Stock Repurchase Program. Stock Compensation: See Note 2 for a discussion of the Company's restricted stock awards. Earnings per Share: The weighted average number of shares of Class A common stock and Class B common stock outstanding used to calculate basic and diluted earnings per share were as follows: 2022 2021 Basic weighted average shares outstanding 7,312 7,146 Dilutive effect of restricted stock awards 61 44 Diluted weighted average shares outstanding 7,373 7,190 Basic earnings per share $ 10.14 $ 6.73 Diluted earnings per share $ 10.06 $ 6.69

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company provides for income taxes and the related accounts under the asset and liability method. Deferred tax assets and liabilities are determined based on the difference between the financial statement and tax bases of assets and liabilities using enacted tax rates expected to be in effect during the year in which the basis differences reverse. Valuation allowances are established when management determines it is more likely than not that some portion, or all, of the deferred tax assets will not be realized. The components of Income before income tax provision and the Income tax provision for the years ended December 31 are as follows: 2022 2021 Income before income tax provision Domestic $ 87,975 $ 57,019 Foreign (252) (169) $ 87,723 $ 56,850 Income tax provision Current income tax provision (benefit): Federal $ 20,761 $ 10,870 State 1,328 1,443 Foreign (53) (35) Total current 22,036 12,278 Deferred income tax (benefit) provision: Federal (8,887) (4,449) State 416 896 Total deferred (8,471) (3,553) $ 13,565 $ 8,725 The Company made income tax payments of $23.4 million and $11.5 million during 2022 and 2021, respectively. During the same periods, income tax refunds totaled $0.1 million and $2.6 million, respectively. The provision for income taxes differs from the amount computed by applying the statutory federal income tax rate to income before the provision for income taxes. A reconciliation of the federal statutory and effective income tax rate for the years ended December 31 is as follows: 2022 2021 Income before income tax provision $ 87,723 $ 56,850 Statutory taxes at 21.0% $ 18,422 $ 11,939 State and local income taxes 1,629 1,890 Non-deductible expenses 745 725 Percentage depletion (4,866) (6,245) R&D and other federal credits (300) (363) Settlements and uncertain tax positions (787) 166 Other, net (1,278) 613 Income tax provision $ 13,565 $ 8,725 Effective income tax rate 15.5 % 15.3 % The Company recorded income tax expense of $13.6 million for the year ended December 31, 2022 on income before income tax of $87.7 million, or 15.5%, compared to income tax expense of $8.7 million on income before income tax of $56.9 million, or 15.3%, for the year ended December 31, 2021. The income tax provision for the year ended December 31, 2022 includes $1.5 million of discrete tax benefits, primarily from the reversal of uncertain tax positions as a result of the conclusion of the IRS examination of the Company’s 2013, 2014, 2015 and 2016 federal income tax returns. Excluding the $1.5 million of discrete tax benefits, the effective income tax rate in 2022 was 17.1%. The year ended December 31, 2021 included $1.0 million of discrete tax expense. Excluding the $1.0 million of discrete tax expense, the effective income tax rate in 2021 was 13.5%. The increase in the effective income tax rate for 2022 compared to 2021, excluding the impact of discrete items, is primarily due to an increase in earnings at entities that do not qualify for percentage depletion. The benefit from percentage depletion is not directly related to the amount of pre-tax income recorded in a period. A detailed summary of the total deferred tax assets and liabilities in the Company's Consolidated Balance Sheets resulting from differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes is as follows: December 31 2022 2021 Deferred tax assets Lease liabilities $ 21,880 $ 24,500 Tax carryforwards 12,398 13,837 Inventories 5,571 4,522 Accrued liabilities 8,176 9,243 Employee benefits 3,086 3,496 Land valuation adjustment 6,261 5,988 Other 6,850 6,527 Total deferred tax assets 64,222 68,113 Less: Valuation allowance 11,809 11,695 52,413 56,418 Deferred tax liabilities Lease right-of-use assets 21,880 24,500 Depreciation and depletion 19,665 25,851 Partnership investment - development costs 6,069 9,840 Accrued pension benefits 10,921 10,941 Total deferred tax liabilities 58,535 71,132 Net deferred liability $ (6,122) $ (14,714) The following table summarizes the tax carryforwards and associated carryforward periods and related valuation allowances where the Company has determined that realization is uncertain: December 31, 2022 Net deferred tax Valuation Carryforwards State net operating loss $ 15,347 $ 14,422 2023-2042 December 31, 2021 Net deferred tax Valuation Carryforwards State net operating loss $ 17,516 $ 14,694 2022-2041 The Company has a valuation allowance for certain state and foreign deferred tax assets. Based upon the review of historical earnings and the relevant expiration of carryforwards, including utilization limitations in the various state taxing jurisdictions, the Company believes the valuation allowances are appropriate and does not expect to release valuation allowances within the next twelve months that would have a significant effect on the Company's financial position or results of operations. Since 2021, the Company has participated in a voluntary program with the IRS called Compliance Assurance Process (“CAP”). The objective of CAP is to contemporaneously work with the IRS to achieve federal tax compliance and resolve all or most issues prior to the filing of the tax return. In general, the Company operates in taxing jurisdictions that provide a statute of limitations period ranging from three to five years for the taxing authorities to review the applicable tax filings. The tax returns of the Company and certain of its subsidiaries are under routine examination by various taxing authorities. The Company has not been informed of any material assessment for which an accrual has not been previously provided and the Company would vigorously contest any material assessment. Management believes any potential adjustment would not materially affect the Company's financial condition or results of operations. The following is a reconciliation of the Company's total gross unrecognized tax benefits, defined as the aggregate tax effect of differences between tax return positions and the benefits recognized in the financial statements for the years ended December 31, 2022 and 2021. Approximately $5.5 million and $6.4 million of the gross unrecognized tax benefits as of December 31, 2022 and 2021, respectively, relate to permanent items that, if recognized, would impact the effective income tax rate. This amount differs from the gross unrecognized tax benefits presented in the table below due to (1) the deferred tax asset which would be available if the position were not sustained upon audit and (2) the decrease in U.S. federal income taxes which would occur upon the recognition of the state tax benefits included herein. 2022 2021 Balance at January 1 $ 10,554 $ 10,459 Additions based on tax positions related to prior years — 95 Decreases based on settlements with tax authorities (928) — Balance at December 31 $ 9,626 $ 10,554 The Company records interest and penalties on uncertain tax positions as a component of the income tax provision. The Company recognized net expense of less than $0.1 million in interest and penalties related to uncertain tax positions during both 2022 and 2021. The total amount of interest and penalties accrued was $0.3 million and $0.2 million as of December 31, 2022 and 2021, respectively.

Retirement Benefit Plans

Retirement Benefit Plans	12 Months Ended
Retirement Benefit Plans	Dec. 31, 2022
Retirement Benefits [Abstract]
Retirement Benefit Plans	Retirement Benefit Plans Defined Benefit Plans: The Company maintains defined benefit pension plans that provide benefits based on years of service and average compensation during certain periods. Prior to 2021, the Company amended the Combined Defined Benefit Plan for NACCO Industries, Inc. and its subsidiaries (the “Combined Plan”) to freeze pension benefits for all employees. The Company also amended the Supplemental Retirement Benefit Plan (the “SERP”) to freeze all pension benefits. All eligible employees of the Company, including employees whose pension benefits are frozen, receive retirement benefits under defined contribution retirement plans. The assumptions used in accounting for the defined benefit plans were as follows for the years ended December 31: 2022 2021 Weighted average discount rates for pension benefit obligation 5.36% - 5.40% 2.53% - 2.77% Weighted average discount rates for net periodic benefit cost 2.53% - 2.77% 2.02% - 2.36% Expected long-term rate of return on assets for net periodic benefit cost 7.00 % 7.00 % Set forth below is detail of the net periodic pension income for the defined benefit plans for the years ended December 31: 2022 2021 Interest cost $ 1,105 $ 1,002 Expected return on plan assets (2,707) (2,568) Amortization of actuarial loss 543 718 Amortization of prior service cost 58 59 Net periodic pension income $ (1,001) $ (789) Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive loss (income) for the years ended December 31: 2022 2021 Current year actuarial (gain) loss $ 1,717 $ (3,793) Amortization of actuarial loss (543) (718) Amortization of prior service cost (58) (59) Total recognized in other comprehensive loss (income) $ 1,116 $ (4,570) The following table sets forth the changes in the benefit obligation and the plan assets during the year and the funded status of the defined benefit plans at December 31: 2022 2021 Change in benefit obligation Projected benefit obligation at beginning of year $ 41,663 $ 44,600 Interest cost 1,105 1,002 Actuarial gain (8,396) (1,367) Benefits paid (2,650) (2,572) Projected benefit obligation at end of year $ 31,722 $ 41,663 Accumulated benefit obligation at end of year $ 31,722 $ 41,663 Change in plan assets Fair value of plan assets at beginning of year $ 44,009 $ 41,099 Actual return on plan assets (7,405) 4,995 Employer contributions 531 487 Benefits paid (2,650) (2,572) Fair value of plan assets at end of year $ 34,485 $ 44,009 Funded status at end of year $ 2,763 $ 2,346 Amounts recognized in the balance sheets consist of: Non-current assets $ 6,991 $ 7,806 Current liabilities (491) (542) Non-current liabilities (3,737) (4,918) $ 2,763 $ 2,346 Components of accumulated other comprehensive loss consist of: Actuarial loss $ 10,682 $ 9,510 Prior service cost 645 703 Deferred taxes (2,490) (2,254) $ 8,837 $ 7,959 The Company recognizes as a component of benefit (income) cost, as of the measurement date, any unrecognized actuarial net gains or losses that exceed 10% of the larger of the projected benefit obligations or the plan assets, defined as the "corridor." Amounts outside the corridor are amortized over the average expected remaining service of active participants expected to benefit under the retiree medical plans or over the average expected remaining lifetime of inactive participants for the pension plans. The (gain) loss amounts recognized in AOCI are not expected to be fully recognized until the plan is terminated or as settlements occur, which would trigger accelerated recognition. Prior service costs resulting from plan changes are also in AOCI. The Company's policy is to make contributions to fund its pension plans within the range allowed by applicable regulations. The Company maintains one supplemental defined benefit plan that pays monthly benefits to participants directly out of corporate funds. All other pension benefit payments are made from assets of the pension plans. Future pension benefit payments expected to be paid from assets of the pension plans are: 2023 $ 2,731 2024 2,729 2025 2,700 2026 2,691 2027 2,681 2028 - 2032 12,536 $ 26,068 The expected long-term rate of return on defined benefit plan assets reflects management's expectations of long-term rates of return on funds invested to provide for benefits included in the projected benefit obligations. In establishing the expected long-term rate of return assumption for plan assets, the Company considers the historical rates of return over a period of time that is consistent with the long-term nature of the underlying obligations of these plans as well as a forward-looking rate of return. The historical and forward-looking rates of return for each of the asset classes used to determine the Company's estimated rate of return assumption were based upon the rates of return earned or expected to be earned by investments in the equivalent benchmark market indices for each of the asset classes. Expected returns for pension plans are based on a calculated market-related value for pension plan assets. Under this methodology, asset gains and losses resulting from actual returns that differ from the Company's expected returns are recognized in the market-related value of assets ratably over three years. The pension plans maintain investment policies that, among other things, establish a portfolio asset allocation methodology with percentage allocation bands for individual asset classes. The investment policies provide that investments are reallocated between asset classes as balances exceed or fall below the appropriate allocation bands. The following is the actual allocation percentage and target allocation percentage for the pension plan assets at December 31: 2022 2021 Target Allocation U.S. equity securities 44.9 % 48.7 % 36.0% - 54.0% Non-U.S. equity securities 20.5 % 19.7 % 16.0% - 24.0% Fixed income securities 34.1 % 31.2 % 30.0% - 40.0% Money market funds 0.5 % 0.4 % 0.0% - 10.0% The defined benefit pension plans do not have any direct ownership of NACCO common stock. The fair value of each major category of the Company's pension plan assets are valued using quoted market prices in active markets for identical assets, or Level 1 in the fair value hierarchy. Following are the values as of December 31: Level 1 2022 2021 U.S. equity securities $ 15,499 $ 21,434 Non-U.S. equity securities 7,055 8,678 Fixed income securities 11,753 13,723 Money market funds 178 174 Total $ 34,485 $ 44,009 Postretirement Health Care: The Company also maintains health care plans which provide benefits to grandfathered eligible retired employees. All health care plans of the Company have a cap on the Company's share of the costs. The health care plans have network provided benefits which result in cost savings for the Company. These plans have no assets. Under the Company's current policy, plan benefits are funded at the time they are due to participants. The assumptions used in accounting for the postretirement health care plans are set forth below for the years ended December 31: 2022 2021 Weighted average discount rates for benefit obligation 5.29 % 2.12 % Weighted average discount rates for net periodic benefit cost 2.12 % 1.37 % Health care cost trend rate assumed for next year 6.25 % 6.50 % Rate to which the cost trend rate is assumed to decline (ultimate trend rate) 4.50% - 4.75% 4.50 % Year that the rate reaches the ultimate trend rate 2029 2029 Set forth below is detail of the net periodic benefit expense for the postretirement health care plans for the years ended December 31: 2022 2021 Service cost $ 12 $ 13 Interest cost 38 27 Amortization of actuarial loss 64 19 Amortization of prior service credit (52) (54) Net periodic benefit expense $ 62 $ 5 Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss for the years ended December 31: 2022 2021 Current year actuarial gain $ (44) $ (48) Amortization of actuarial loss (64) (19) Amortization of prior service credit 52 54 Transfers — 126 Total recognized in other comprehensive (income) loss $ (56) $ 113 The following sets forth the changes in benefit obligations during the year and the funded status of the postretirement health care at December 31: 2022 2021 Change in benefit obligation Benefit obligation at beginning of year $ 1,877 $ 2,054 Service cost 12 13 Interest cost 38 27 Actuarial gain (44) (48) Benefits paid (332) (169) Benefit obligation at end of year $ 1,551 $ 1,877 Funded status at end of year $ (1,551) $ (1,877) Amounts recognized in the balance sheets consist of: Current liabilities $ (206) $ (190) Noncurrent liabilities (1,345) (1,687) $ (1,551) $ (1,877) Components of accumulated other comprehensive loss consist of: Actuarial loss $ 412 $ 520 Prior service credit (56) (108) Deferred taxes (180) (195) $ 176 $ 217 Future postretirement health care benefit payments expected to be paid are: 2023 211 2024 188 2025 179 2026 183 2027 185 2028 - 2032 654 $ 1,600

Business Segments

Business Segments	12 Months Ended
Business Segments	Dec. 31, 2022
Segment Reporting [Abstract]
Business Segments	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 which are not included as part of the measurement of segment operating profit, which are 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. Effective January 1, 2022, the Company changed the composition of its reportable segments. As a result, the Company retrospectively changed its computation of segment operating profit to reclassify the results of Caddo Creek Resources Company, LLC (“Caddo Creek”) and Demery Resources Company, LLC ("Demery") from the Coal Mining segment into the NAMining segment as these operations provide mining solutions for producers of industrial minerals, rather than for power generation. The Coal Mining segment now includes only mines that deliver coal to power generation companies. This segment reporting change has no impact on consolidated operating results. All prior period segment information has been reclassified to conform to the new presentation. 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-K on a consolidated basis. See Note 1 for additional discussion of the Company's reportable segments. All current operations reside in the U.S. The accounting policies of the reportable segments are described in Note 2 and Note 18. In 2022 and 2021, two customers individually accounted for more than 10% of consolidated revenue. The following represents the revenue attributable to each of these entities as a percentage of consolidated revenue for those years: Percentage of Consolidated Revenue Segment 2022 2021 Coal Mining customer 39 % 43 % NAMining customer 17 % 19 % The following tables present revenue, operating profit, depreciation expense and capital expenditures for the years ended December 31: 2022 2021 Revenues Coal Mining $ 95,204 $ 82,831 NAMining 85,664 78,944 Minerals Management 60,242 31,003 Unallocated Items 2,952 4,695 Eliminations (2,343) (5,627) Total $ 241,719 $ 191,846 Operating profit (loss) Coal Mining $ 38,309 $ 45,784 NAMining 2,202 3,384 Minerals Management 52,214 26,080 Unallocated Items (23,233) (19,553) Eliminations 494 (285) Total $ 69,986 $ 55,410 Expenditures for property, plant and equipment and acquisition of mineral interests Coal Mining $ 14,853 $ 16,830 NAMining 13,203 21,100 Minerals Management 13,388 6,423 Unallocated Items 13,003 208 Total $ 54,447 $ 44,561 Depreciation, depletion and amortization Coal Mining $ 17,074 $ 16,510 NAMining 6,457 4,574 Minerals Management 3,026 1,858 Unallocated Items 259 143 Total $ 26,816 $ 23,085 Asset information by segment is not discretely maintained for internal reporting or used in evaluating performance.

Unconsolidated Subsidiaries

Unconsolidated Subsidiaries	12 Months Ended
Unconsolidated Subsidiaries	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Unconsolidated Subsidiaries	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 $14.9 million and $19.1 million at December 31, 2022 and 2021, respectively. The Company's risk of loss relating to these entities is limited to its invested capital, which was $7.1 million and $7.6 million at December 31, 2022 and 2021, respectively. NACoal is a party to certain guarantees related to Coyote Creek. Under certain circumstances of default or termination of Coyote Creek’s Lignite Sales Agreement (“LSA”), NACoal would be obligated for payment of a "make-whole" amount to Coyote Creek’s third-party lenders. The “make-whole” amount is based on the excess, if any, of the discounted value of the remaining scheduled debt payments over the principal amount. In addition, in the event Coyote Creek’s LSA is terminated on or after January 1, 2024 by Coyote Creek’s customers, NACoal is obligated to purchase Coyote Creek’s dragline and rolling stock for the then net book value of those assets. To date, no payments have been required from NACoal since the inception of these guarantees. The Company believes that the likelihood NACoal would be required to perform under the guarantees is remote, and no amounts related to these guarantees have been recorded. Summarized financial information for the unconsolidated subsidiaries is as follows: 2022 2021 Statement of Operations Revenue $ 664,824 $ 764,759 Gross profit $ 47,748 $ 68,076 Income before income taxes $ 57,250 $ 60,865 Net income $ 48,467 $ 53,248 Balance Sheet Current assets $ 214,098 $ 168,669 Non-current assets $ 805,833 $ 900,924 Current liabilities $ 116,701 $ 98,887 Non-current liabilities $ 896,134 $ 963,128 Revenue includes all mine operating costs that are reimbursed by the customers of the Unconsolidated Subsidiaries as well as the compensation per ton of coal, heating unit (MMBtu) or ton of limestone delivered. Reimbursed costs have offsetting expenses and have no impact on income before income taxes. Income before income taxes represents the Earnings of the unconsolidated operations. NACoal received dividends of $49.0 million and $51.7 million from the Unconsolidated Subsidiaries in 2022 and 2021, respectively.

Related Party Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2022
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions One of the Company's directors is a retired Jones Day partner. Legal services rendered by Jones Day approximated $1.0 million and $1.2 million for the years ended December 31, 2022 and 2021. Alfred M. Rankin, Jr. serves as the Chairman of the Board of Directors of NACCO and supports the President and Chief Executive Officer of NACCO upon request under the terms of a consulting agreement. Fees for consulting services rendered by Mr. Rankin approximated $0.3 million and $0.5 million for the years ended December 31, 2022 and 2021, respectively. Hyster-Yale Materials Handling, Inc. ("Hyster-Yale") is a former subsidiary of the Company that was spun-off to stockholders in 2012. Mr. Rankin is Chairman, President and Chief Executive Officer of Hyster-Yale Materials Handling and Chairman, Hyster-Yale Group. In the ordinary course of business, NACoal leases or buys Hyster-Yale lift trucks. The terms may not be comparable to terms that would be obtained in a transaction between unaffiliated parties.

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
Supplemental Oil and Gas Disclosures (Unaudited)	Dec. 31, 2022
Extractive Industries [Abstract]
Supplemental Oil and Gas Disclosures (Unaudited)	Supplemental Oil and Gas Disclosures (Unaudited) 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. 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 working interests in oil and natural gas operations because detailed information is not generally available to owners of royalty and mineral interests. See Note 1, Note 2 and Note 15 for additional discussion of the Minerals Management segment. Aggregate capitalized costs related to oil and gas royalty and mineral interests with applicable accumulated depreciation, depletion and amortization at December 31 are as follows: 2022 2021 Proved developed $ 7,302 $ 3,266 Proved undeveloped 24,134 16,246 Proved reserves 31,436 19,512 Less: accumulated depreciation, depletion and amortization 1,936 868 Net royalty interests in oil and natural gas properties $ 29,500 $ 18,644 Total net proved reserves are defined as those natural gas and hydrocarbon liquid reserves to Company interests after deducting all royalties, overriding royalties, and reversionary interests owned by outside parties that become effective upon payout of specified monetary balances. Decline curve analysis was used to estimate the remaining reserves of pressure depletion reservoirs with enough historical production data to establish decline trends. Reservoirs under non-pressure depletion drive mechanisms and non-producing reserves were estimated by volumetric analysis, research of analogous reservoirs, or a combination of both. Reserves have been estimated using deterministic and probabilistic methods. All reserves estimates have been prepared using standard engineering practices generally accepted by the petroleum industry and conform to guidelines developed and adopted by the SEC. The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31 based on the reserve report prepared by Haas Engineering, the Company’s independent petroleum engineering firm. All of the Company’s reserves are located in the United States. Net reserves as of December 31, 2022 Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) Proved developed 305,710 408,280 25,907,890 Proved undeveloped 32,570 11,030 1,784,670 Total 338,280 419,310 27,692,560 Net reserves as of December 31, 2021 Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) Proved developed 167,430 282,230 16,617,360 Proved undeveloped 220 90 1,210 Total 167,650 282,320 16,618,570 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases. Estimated Proved Reserves The following table summarizes changes in proved reserves during the year ended December 31, 2022: Estimated Proved Reserves Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) December 31, 2021 167,650 282,320 16,618,570 Purchases 99,345 35,222 202,314 Extensions and discoveries 121,542 68,167 12,801,109 Revisions of previous estimates (3) (2,504) 95,577 5,405,803 Production (46,571) (61,511) (7,329,985) Other (1,182) (465) (5,251) December 31, 2022 338,280 419,310 27,692,560 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases. (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors. Estimated Proved Undeveloped Reserves ("PUDs") The following table summarizes changes in PUDs during the year ended December 31, 2022: Estimated Proved Undeveloped Reserves Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) December 31, 2021 220 90 1,210 Purchases 21,790 5,104 38,571 Extensions and discoveries 10,780 5,926 1,746,099 Revisions of previous estimates (3) (220) (90) (1,210) December 31, 2022 32,570 11,030 1,784,670 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases. (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors. As an owner of mineral and royalty interests, the Company generally does not have evidence of approval of operators’ development plans. As a result, proved undeveloped reserve estimates are limited to those relatively few locations for which drilling permits have been publicly filed. As of December 31, 2022, PUD reserves consists of 42 wells in various stages of drilling or completions. As of December 31, 2022, approximately 6% of the Company's total proved reserves were classified as PUDs. Standardized Measure of Discounted Future Net Cash Flows Future cash inflows represent expected revenues from production of period-end quantities of proved reserves based on the 12-month unweighted average of first-day-of-the-month commodity prices for the periods presented. Future cash inflows are computed by applying applicable prices relating to proved reserves to the year-end quantities of those reserves. Future production and costs are derived based on current costs assuming continuation of existing economic conditions. Federal income tax expenses are deducted from future production revenues in the calculation of the standardized measure using the statutory tax rate. The Company is subject to certain state-based taxes; however, these amounts are not material. The projections should not be viewed as realistic estimates of future cash flows, nor should the “standardized measure” be interpreted as representing current value to the Company. Material revisions to estimates of proved reserves may occur in the future; development and production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from those used; and actual costs may vary. The following table provides the future net cash flows relating to proved oil and gas reserves based on the standardized measure of discounted cash flows as of December 31, 2022 : Gross Amounts Statutory tax rate Net Amounts Future cash inflows $ 218,982 Future production costs 39,841 Future net cash flows before income tax expense 179,141 21 % 141,521 10% discount to reflect timing of cash flows (62,615) 21 % (49,465) Standardized measure of discounted cash flows $ 116,526 21 % $ 92,056 The following table provides the future net cash flows relating to proved oil and gas reserves based on the standardized measure of discounted cash flows as of December 31, 2021 : Gross Amounts Statutory tax rate Net Amounts Future cash inflows $ 71,400 Future production costs 14,664 Future net cash flows before income tax expense 56,736 21 % 44,821 10% discount to reflect timing of cash flows (19,897) 21 % (15,719) Standardized measure of discounted cash flows $ 36,839 21 % $ 29,102 The following summarizes the principal sources of change in the standardized measure of discounted future net cash flows during 2022: Gross amounts December 31, 2021 $ 36,839 Purchases 6,236 Extensions and discoveries 54,795 Revisions of previous estimates (3) 18,695 Other (39) December 31, 2022 $ 116,526 (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
Schedule II - Valuation and Qualifying Accounts	Dec. 31, 2022
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS NACCO INDUSTRIES, INC. AND SUBSIDIARIES YEAR ENDED DECEMBER 31, 2022 AND 2021 Additions Description Balance at Beginning of Period Charged to Charged to Deductions Balance at (In thousands) 2022 Reserves deducted from asset accounts: Deferred tax valuation allowances $ 11,695 $ 114 $ — $ — $ 11,809 2021 Reserves deducted from asset accounts: Deferred tax valuation allowances $ 11,549 $ 146 $ — $ — $ 11,695 (A) Balances which are not required to be presented and those which are immaterial have been omitted.

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
Significant Accounting Policies (Policies)	Dec. 31, 2022
Accounting Policies [Abstract]
Use of Estimates	Use of Estimates: The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and judgments. These estimates and judgments affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities (if any) at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents: Cash and cash equivalents include cash in banks and highly liquid investments with original maturities of three months or less.
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net: Property, plant and equipment are initially recorded at cost. Depreciation, depletion and amortization are provided in amounts sufficient to amortize the cost of the assets, including assets recorded under finance leases, over their estimated useful lives using the straight-line method or the units-of-production method. Buildings and three
Royalty Interests in Oil and Natural Gas Properties	Royalty Interests in Oil and Natural Gas Properties: The Company follows the successful efforts method of accounting for its royalty and mineral interests. Under this method, costs to acquire mineral and royalty interests in oil and natural gas properties are capitalized when incurred. Acquisitions of royalty interests of oil and natural gas properties are considered asset acquisitions and are recorded at cost. As an owner of mineral and royalty interests and not working interests, the Company is not required to make capital expenditures and did not make capital expenditures to convert proved undeveloped reserves from undeveloped to developed. Acquisition costs of proved royalty and mineral interests are amortized using the units of production method over the life of the property, which is estimated using proved reserves. For purposes of amortization, interests in oil and natural gas properties are grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic condition. The Company reviews and evaluates its royalty interests in oil and natural gas properties for impairment when events or changes in circumstances indicate that the related carrying amounts may not be recoverable. Proved oil and gas properties are reviewed for impairment when events and circumstances indicate a potential decline in the fair value of such properties below the carrying value, such as a downward revision of the reserve estimates or lower commodity prices. When such events or changes in circumstances occur, the Company estimates the undiscounted future cash flows expected in connection with the properties and compares such future cash flows to the carrying amounts of the properties to determine if the carrying amounts are recoverable. If the carrying value of the properties is determined to not be recoverable based on the undiscounted cash flows, an impairment charge is recognized by comparing the carrying value to the estimated fair value of the properties.
Long-Lived Assets	Long-Lived Assets: The Company periodically evaluates long-lived assets for impairment when changes in circumstances or the occurrence of certain events indicate the carrying amount of an asset or asset group may not be recoverable. Upon identification of indicators of impairment, the Company evaluates the carrying value of the asset by comparing the estimated future undiscounted cash flows generated from the use of the asset or asset group and its eventual disposition with the asset's net carrying value. If the carrying value of an asset is considered impaired, an impairment charge is recorded for the amount that the carrying value of the long-lived asset or asset group exceeds its fair value. Fair value is estimated as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. See Note 9 for further discussion of the Company's nonrecurring fair value measurements. At MLMC, the costs of mining operations are not reimbursed by MLMC's customer. As such, increased costs at MLMC or decreased revenues could materially reduce the Company's profitability. Any reduction in customer demand at MLMC, including reductions related to reduced mechanical availability of the customer’s power plant, would adversely affect the Company's operating results and could result in significant impairments. MLMC has approximately $125 million of long-lived assets, including property, plant and equipment and its coal supply agreement intangible asset, which are subject to periodic impairment analyses and review. Identifying and assessing whether impairment indicators exist, or if events or changes in circumstances have occurred, including assumptions about future power plant dispatch levels, changes in future sales price, operating costs and other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual future operating results could differ significantly from these estimates, which may result in an impairment charge in a future period, which could have a substantial impact on the Company’s results of operations.
Self-insurance Liabilities	Self-insurance Liabilities: The Company is generally self-insured for medical claims, certain workers’ compensation claims and certain closed mine liabilities. An estimated provision for claims reported and for claims incurred but not yet reported under the self-insurance programs is recorded and revised periodically based on industry trends, historical experience and management judgment. In addition, industry trends are considered within management's judgment for valuing claims. Changes in assumptions for such matters as legal judgments and settlements, inflation rates, medical costs and actual experience could cause estimates to change in the near term.
Stock Compensation	Stock Compensation: The Company maintains long-term incentive programs that allow for the grant of shares of Class A common stock, subject to restrictions, as a means of retaining and rewarding selected employees for long-term performance and to increase ownership in the Company. Shares awarded under the plans are fully vested and entitle the stockholder to all rights of common stock ownership except that shares may not be assigned, pledged or otherwise transferred during the restriction period. In general, for shares awarded for years ended December 31, 2022 and December 31, 2021, the restriction period ends at the earliest of (i) three years after the participant's retirement date, (ii) three five The Company also has a stock compensation plan for non-employee directors of the Company under which a portion of the annual retainer for each non-employee director is paid in restricted shares of Class A common stock. For the year ended December 31, 2022, $110,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $175,000 ($250,000 for the Chairman) was paid in restricted shares of Class A common stock. For the year ended December 31, 2021, $105,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $167,000 ($250,000 for the Chairman) was paid in restricted shares of Class A common stock. Shares awarded under the plan are fully vested and entitle the stockholder to all rights of common stock ownership except that shares may not be assigned, pledged, hypothecated or otherwise transferred during the restriction period. In general, the restriction period ends at the earliest of (i) ten years from the award date, (ii) the date of the director's death or permanent disability, (iii) five years (or earlier with the approval of the Board of Directors) after the director's date of retirement from the Board of Directors, (iv) the date the director has both retired from the Board of Directors and has reached age 70, or (v) at such other time as determined by the Board of Directors in its sole and absolute discretion. Pursuant to this plan, the Company issued 30,034 and 45,223 shares related to the years ended December 31, 2022 and 2021, respectively. In addition to the mandatory retainer fee received in restricted stock, directors may elect to receive shares of Class A common stock in lieu of cash for up to 100% of the balance of their annual retainer, committee retainer and any committee chairman's fees. These voluntary shares are not subject to any restrictions. Total shares issued under voluntary elections were 480 in 2022 and 753 in 2021. After the issuance of these shares, there were 136,047 shares of Class A common stock available for issuance under this plan. Compensation expense related to these awards was $1.3 million ($1.0 million net of tax) and $1.3 million ($1.1 million net of tax) for the years ended December 31, 2022 and 2021, respectively. Compensation expense represents fair value based on the market price of the shares of Class A common stock at the grant date.
Financial Instruments	Financial Instruments: Financial instruments held by the Company include cash and cash equivalents, accounts receivable, equity securities, accounts payable, revolving credit agreements and long-term debt.
Fair Value Measurements	Fair Value Measurements: The Company accounts for the fair value measurement of its financial assets and liabilities in accordance with U.S. generally accepted accounting principles, which defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy requires an entity to maximize the use of observable inputs, where available, and minimize the use of unobservable inputs when measuring fair value. Described below are the three levels of inputs that may be used to measure fair value: Level 1 - Quoted prices in active markets that are accessible at the measurement date for identical assets or liabilities. Level 2 - Observable prices that are based on inputs not quoted on active markets, but corroborated by market data. Level 3 - Unobservable inputs are used when little or no market data is available. The hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. The classification of fair value measurements within the hierarchy is based upon the lowest level of input that is significant to the measurement. See Note 9 for further discussion of fair value measurements.

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
Revenue Recognition (Tables)	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table disaggregates revenue by major sources for the years ended December 31: Major Goods/Service Lines 2022 2021 Coal Mining $ 95,204 $ 82,831 NAMining 85,664 78,944 Minerals Management 60,242 31,003 Unallocated Items 2,952 4,695 Eliminations (2,343) (5,627) Total revenues $ 241,719 $ 191,846 Timing of Revenue Recognition Goods transferred at a point in time $ 92,842 $ 80,515 Services transferred over time 148,877 111,331 Total revenues $ 241,719 $ 191,846
Contract Balances	The opening and closing balances of the Company’s current and long-term contract assets and liabilities and receivables are as follows: Contract balances Trade accounts receivable Contract asset Contract asset Contract liability (current) Contract liability (long-term) Balance at January 1, 2022 $ 25,667 $ — $ 5,985 $ 4,082 $ 1,453 Balance at December 31, 2022 37,940 409 5,985 833 1,709 Increase (decrease) $ 12,273 $ 409 $ — $ (3,249) $ 256

Inventories (Tables)

Inventories (Tables)	12 Months Ended
Inventories (Tables)	Dec. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventories are summarized as follows: December 31 2022 2021 Coal $ 27,927 $ 19,352 Mining supplies 43,561 34,733 Total inventories $ 71,488 $ 54,085

Property, Plant and Equipment_2

Property, Plant and Equipment, Net (Tables)	12 Months Ended
Property, Plant and Equipment, Net (Tables)	Dec. 31, 2022
Property, Plant and Equipment, Net [Abstract]
Property, Plant and Equipment	Property, plant and equipment, net includes the following: December 31 2022 2021 Coal lands and real estate $ 60,277 $ 52,011 Mineral interests 31,436 19,512 Plant and equipment 290,511 264,110 Property, plant and equipment, at cost 382,224 335,633 Less allowances for depreciation, depletion and amortization 164,272 142,466 $ 217,952 $ 193,167

Intangible Assets (Tables)

Intangible Assets (Tables)	12 Months Ended
Intangible Assets (Tables)	Dec. 31, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	The gross and net balances are set forth in the following table: Gross Carrying Accumulated Net Balance at December 31, 2022 Coal supply agreement $ 84,200 $ (56,145) $ 28,055 Balance at December 31, 2021 Coal supply agreement $ 84,200 $ (52,426) $ 31,774

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	A reconciliation of the Company's beginning and ending aggregate carrying amount of the asset retirement obligations are as follows: Coal Mining Unallocated Items NACCO Balance at January 1, 2021 $ 25,040 $ 16,692 $ 41,732 Liabilities settled during the period (184) (869) (1,053) Accretion expense 1,996 1,304 3,300 Revision of estimated cash flows 46 (74) (28) Balance at December 31, 2021 $ 26,898 $ 17,053 $ 43,951 Liabilities settled during the period (223) (956) (1,179) Accretion expense 2,190 1,332 3,522 Revision of estimated cash flows (405) 113 (292) Balance at December 31, 2022 $ 28,460 $ 17,542 $ 46,002

Current and Long-Term Financi_2

Current and Long-Term Financing (Tables)	12 Months Ended
Current and Long-Term Financing (Tables)	Dec. 31, 2022
Debt Disclosure [Abstract]
Schedule of Debt	The following table summarizes the Company's available and outstanding borrowings: December 31 2022 2021 Total outstanding borrowings of NACoal: Revolving credit agreement $ — $ 4,000 Other debt 19,668 16,710 Total debt outstanding $ 19,668 $ 20,710 Current portion of borrowings outstanding $ 3,649 $ 2,527 Long-term portion of borrowings outstanding 16,019 18,183 $ 19,668 $ 20,710 Total available borrowings, net of limitations, under revolving credit agreement $ 116,285 $ 120,231 Unused revolving credit agreement $ 116,285 $ 116,231 Weighted average stated interest rate on total borrowings 3.9 % 3.7 %
Schedule of Maturities of Total Debt, Excluding Capital Leases	Annual maturities of total debt, excluding leases, are as follows: 2023 2,873 2024 2,497 2025 1,620 2026 5,955 2027 236 Thereafter 5,692 $ 18,873

Fair Value Disclosure (Tables)

Fair Value Disclosure (Tables)	12 Months Ended
Fair Value Disclosure (Tables)	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table presents the Company's assets accounted for at fair value on a recurring basis: Fair Value Measurements at Reporting Date Using Quoted Prices in Significant Active Markets for Significant Other Unobservable Identical Assets Observable Inputs Inputs Description December 31, 2022 (Level 1) (Level 2) (Level 3) Assets: Equity securities $ 15,534 $ 15,534 $ — $ — $ 15,534 $ 15,534 $ — $ — Fair Value Measurements at Reporting Date Using Quoted Prices in Significant Active Markets for Significant Other Unobservable Identical Assets Observable Inputs Inputs Description December 31, 2021 (Level 1) (Level 2) (Level 3) Assets: Equity securities $ 16,070 $ 16,070 $ — $ — $ 16,070 $ 16,070 $ — $ —

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 2022
Leases [Abstract]
Schedule of Leased Assets and Liabilities	Leased assets and liabilities include the following at December 31: Description Location 2022 2021 Assets Operating Operating lease right-of-use assets $ 6,419 $ 8,911 Finance Property, plant and equipment, net (a) 843 334 Liabilities Current Operating Other current liabilities $ 1,039 $ 1,463 Finance Current maturities of long-term debt 776 150 Non-current Operating Operating lease liabilities $ 7,528 $ 9,733 Finance Long-term debt 19 190 (a) Finance leased assets are recorded net of accumulated amortization of $0.2 million and $0.3 million as of December 31, 2022 and December 31, 2021, respectively.
Lease Expense	The components of lease expense for the years ended December 31 are as follows: Description Location 2022 2021 Lease expense Operating lease cost Selling, general and administrative expenses $ 1,881 $ 2,122 Finance lease cost: Amortization of leased assets Cost of sales 128 220 Interest on lease liabilities Interest expense 13 31 Variable lease expense Selling, general and administrative expenses 534 571 Short-term lease expense Selling, general and administrative expenses 3,434 1,176 Total lease expense $ 5,990 $ 4,120
Finance Leases, Future Minimum Payments	Future minimum finance and operating lease payments were as follows at December 31, 2022: Finance Leases Operating Leases Total 2023 $ 778 $ 1,599 $ 2,377 2024 12 1,474 1,486 2025 7 1,283 1,290 2026 — 1,314 1,314 2027 — 1,345 1,345 Subsequent to 2027 — 4,177 4,177 Total minimum lease payments 797 11,192 $ 11,989 Amounts representing interest 2 2,625 Present value of net minimum lease payments $ 795 $ 8,567
Operating Leases, Future Minimum Payments	Future minimum finance and operating lease payments were as follows at December 31, 2022: Finance Leases Operating Leases Total 2023 $ 778 $ 1,599 $ 2,377 2024 12 1,474 1,486 2025 7 1,283 1,290 2026 — 1,314 1,314 2027 — 1,345 1,345 Subsequent to 2027 — 4,177 4,177 Total minimum lease payments 797 11,192 $ 11,989 Amounts representing interest 2 2,625 Present value of net minimum lease payments $ 795 $ 8,567
Assumptions Used for Leases	The assumptions used in accounting for ASC 842 for the years ended December 31 are as follows: 2022 2021 Weighted average remaining lease term (years) Operating 7.66 8.38 Finance 1.41 2.44 Weighted average discount rate Operating 7.13 % 7.08 % Finance 3.11 % 4.16 %
Supplemental Cash Flow Information	The following table details cash paid for amounts included in the measurement of lease liabilities for the years ended December 31: 2022 2021 Operating cash flows from operating leases $ 2,097 $ 2,260 Operating cash flows from finance leases 13 31 Financing cash flows from finance leases 183 275

Stockholders' Equity and Earn_2

Stockholders' Equity and Earnings Per Share (Tables)	12 Months Ended
Stockholders' Equity and Earnings Per Share (Tables)	Dec. 31, 2022
Equity [Abstract]
Schedule of Earnings Per Share	The weighted average number of shares of Class A common stock and Class B common stock outstanding used to calculate basic and diluted earnings per share were as follows: 2022 2021 Basic weighted average shares outstanding 7,312 7,146 Dilutive effect of restricted stock awards 61 44 Diluted weighted average shares outstanding 7,373 7,190 Basic earnings per share $ 10.14 $ 6.73 Diluted earnings per share $ 10.06 $ 6.69

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Schedule of Income Before Income Tax Provision	The components of Income before income tax provision and the Income tax provision for the years ended December 31 are as follows: 2022 2021 Income before income tax provision Domestic $ 87,975 $ 57,019 Foreign (252) (169) $ 87,723 $ 56,850 Income tax provision Current income tax provision (benefit): Federal $ 20,761 $ 10,870 State 1,328 1,443 Foreign (53) (35) Total current 22,036 12,278 Deferred income tax (benefit) provision: Federal (8,887) (4,449) State 416 896 Total deferred (8,471) (3,553) $ 13,565 $ 8,725
Effective Income Tax Rate Reconciliation	A reconciliation of the federal statutory and effective income tax rate for the years ended December 31 is as follows: 2022 2021 Income before income tax provision $ 87,723 $ 56,850 Statutory taxes at 21.0% $ 18,422 $ 11,939 State and local income taxes 1,629 1,890 Non-deductible expenses 745 725 Percentage depletion (4,866) (6,245) R&D and other federal credits (300) (363) Settlements and uncertain tax positions (787) 166 Other, net (1,278) 613 Income tax provision $ 13,565 $ 8,725 Effective income tax rate 15.5 % 15.3 %
Deferred Tax Assets and Liabilities	A detailed summary of the total deferred tax assets and liabilities in the Company's Consolidated Balance Sheets resulting from differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes is as follows: December 31 2022 2021 Deferred tax assets Lease liabilities $ 21,880 $ 24,500 Tax carryforwards 12,398 13,837 Inventories 5,571 4,522 Accrued liabilities 8,176 9,243 Employee benefits 3,086 3,496 Land valuation adjustment 6,261 5,988 Other 6,850 6,527 Total deferred tax assets 64,222 68,113 Less: Valuation allowance 11,809 11,695 52,413 56,418 Deferred tax liabilities Lease right-of-use assets 21,880 24,500 Depreciation and depletion 19,665 25,851 Partnership investment - development costs 6,069 9,840 Accrued pension benefits 10,921 10,941 Total deferred tax liabilities 58,535 71,132 Net deferred liability $ (6,122) $ (14,714)
Summary of Tax Credit Carryforwards	The following table summarizes the tax carryforwards and associated carryforward periods and related valuation allowances where the Company has determined that realization is uncertain: December 31, 2022 Net deferred tax Valuation Carryforwards State net operating loss $ 15,347 $ 14,422 2023-2042 December 31, 2021 Net deferred tax Valuation Carryforwards State net operating loss $ 17,516 $ 14,694 2022-2041
Unrecognized Tax Benefits Roll Forward	The following is a reconciliation of the Company's total gross unrecognized tax benefits, defined as the aggregate tax effect of differences between tax return positions and the benefits recognized in the financial statements for the years ended December 31, 2022 and 2021. Approximately $5.5 million and $6.4 million of the gross unrecognized tax benefits as of December 31, 2022 and 2021, respectively, relate to permanent items that, if recognized, would impact the effective income tax rate. This amount differs from the gross unrecognized tax benefits presented in the table below due to (1) the deferred tax asset which would be available if the position were not sustained upon audit and (2) the decrease in U.S. federal income taxes which would occur upon the recognition of the state tax benefits included herein. 2022 2021 Balance at January 1 $ 10,554 $ 10,459 Additions based on tax positions related to prior years — 95 Decreases based on settlements with tax authorities (928) — Balance at December 31 $ 9,626 $ 10,554

Retirement Benefit Plans (Table

Retirement Benefit Plans (Tables)	12 Months Ended
Retirement Benefit Plans (Tables)	Dec. 31, 2022
Retirement Benefits [Abstract]
Assumptions Used in Accounting for the Defined Benefit Plan	The assumptions used in accounting for the defined benefit plans were as follows for the years ended December 31: 2022 2021 Weighted average discount rates for pension benefit obligation 5.36% - 5.40% 2.53% - 2.77% Weighted average discount rates for net periodic benefit cost 2.53% - 2.77% 2.02% - 2.36% Expected long-term rate of return on assets for net periodic benefit cost 7.00 % 7.00 % The assumptions used in accounting for the postretirement health care plans are set forth below for the years ended December 31: 2022 2021 Weighted average discount rates for benefit obligation 5.29 % 2.12 % Weighted average discount rates for net periodic benefit cost 2.12 % 1.37 % Health care cost trend rate assumed for next year 6.25 % 6.50 % Rate to which the cost trend rate is assumed to decline (ultimate trend rate) 4.50% - 4.75% 4.50 % Year that the rate reaches the ultimate trend rate 2029 2029
Net Periodic Benefit Income and Expense For the Defined Benefit Plan	Set forth below is detail of the net periodic pension income for the defined benefit plans for the years ended December 31: 2022 2021 Interest cost $ 1,105 $ 1,002 Expected return on plan assets (2,707) (2,568) Amortization of actuarial loss 543 718 Amortization of prior service cost 58 59 Net periodic pension income $ (1,001) $ (789) Set forth below is detail of the net periodic benefit expense for the postretirement health care plans for the years ended December 31: 2022 2021 Service cost $ 12 $ 13 Interest cost 38 27 Amortization of actuarial loss 64 19 Amortization of prior service credit (52) (54) Net periodic benefit expense $ 62 $ 5
Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Loss (Income)	Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive loss (income) for the years ended December 31: 2022 2021 Current year actuarial (gain) loss $ 1,717 $ (3,793) Amortization of actuarial loss (543) (718) Amortization of prior service cost (58) (59) Total recognized in other comprehensive loss (income) $ 1,116 $ (4,570) Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss for the years ended December 31: 2022 2021 Current year actuarial gain $ (44) $ (48) Amortization of actuarial loss (64) (19) Amortization of prior service credit 52 54 Transfers — 126 Total recognized in other comprehensive (income) loss $ (56) $ 113
Changes in Benefit Obligations During the Year and Funded Status of Defined Benefit Plan	The following table sets forth the changes in the benefit obligation and the plan assets during the year and the funded status of the defined benefit plans at December 31: 2022 2021 Change in benefit obligation Projected benefit obligation at beginning of year $ 41,663 $ 44,600 Interest cost 1,105 1,002 Actuarial gain (8,396) (1,367) Benefits paid (2,650) (2,572) Projected benefit obligation at end of year $ 31,722 $ 41,663 Accumulated benefit obligation at end of year $ 31,722 $ 41,663 Change in plan assets Fair value of plan assets at beginning of year $ 44,009 $ 41,099 Actual return on plan assets (7,405) 4,995 Employer contributions 531 487 Benefits paid (2,650) (2,572) Fair value of plan assets at end of year $ 34,485 $ 44,009 Funded status at end of year $ 2,763 $ 2,346 Amounts recognized in the balance sheets consist of: Non-current assets $ 6,991 $ 7,806 Current liabilities (491) (542) Non-current liabilities (3,737) (4,918) $ 2,763 $ 2,346 Components of accumulated other comprehensive loss consist of: Actuarial loss $ 10,682 $ 9,510 Prior service cost 645 703 Deferred taxes (2,490) (2,254) $ 8,837 $ 7,959 The following sets forth the changes in benefit obligations during the year and the funded status of the postretirement health care at December 31: 2022 2021 Change in benefit obligation Benefit obligation at beginning of year $ 1,877 $ 2,054 Service cost 12 13 Interest cost 38 27 Actuarial gain (44) (48) Benefits paid (332) (169) Benefit obligation at end of year $ 1,551 $ 1,877 Funded status at end of year $ (1,551) $ (1,877) Amounts recognized in the balance sheets consist of: Current liabilities $ (206) $ (190) Noncurrent liabilities (1,345) (1,687) $ (1,551) $ (1,877) Components of accumulated other comprehensive loss consist of: Actuarial loss $ 412 $ 520 Prior service credit (56) (108) Deferred taxes (180) (195) $ 176 $ 217
Future Benefit Payments	Future pension benefit payments expected to be paid from assets of the pension plans are: 2023 $ 2,731 2024 2,729 2025 2,700 2026 2,691 2027 2,681 2028 - 2032 12,536 $ 26,068 Future postretirement health care benefit payments expected to be paid are: 2023 211 2024 188 2025 179 2026 183 2027 185 2028 - 2032 654 $ 1,600
Actual Allocation Percentage and Target Allocation Percentage for Pension Plan Assets	The following is the actual allocation percentage and target allocation percentage for the pension plan assets at December 31: 2022 2021 Target Allocation U.S. equity securities 44.9 % 48.7 % 36.0% - 54.0% Non-U.S. equity securities 20.5 % 19.7 % 16.0% - 24.0% Fixed income securities 34.1 % 31.2 % 30.0% - 40.0% Money market funds 0.5 % 0.4 % 0.0% - 10.0%
Fair Value of Pension Plan Assets	The fair value of each major category of the Company's pension plan assets are valued using quoted market prices in active markets for identical assets, or Level 1 in the fair value hierarchy. Following are the values as of December 31: Level 1 2022 2021 U.S. equity securities $ 15,499 $ 21,434 Non-U.S. equity securities 7,055 8,678 Fixed income securities 11,753 13,723 Money market funds 178 174 Total $ 34,485 $ 44,009

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
Business Segments (Tables)	Dec. 31, 2022
Segment Reporting [Abstract]
Schedule of Revenue by Major Customers by Reporting Segments	The following represents the revenue attributable to each of these entities as a percentage of consolidated revenue for those years: Percentage of Consolidated Revenue Segment 2022 2021 Coal Mining customer 39 % 43 % NAMining customer 17 % 19 %
Segment Reporting Information	The following tables present revenue, operating profit, depreciation expense and capital expenditures for the years ended December 31: 2022 2021 Revenues Coal Mining $ 95,204 $ 82,831 NAMining 85,664 78,944 Minerals Management 60,242 31,003 Unallocated Items 2,952 4,695 Eliminations (2,343) (5,627) Total $ 241,719 $ 191,846 Operating profit (loss) Coal Mining $ 38,309 $ 45,784 NAMining 2,202 3,384 Minerals Management 52,214 26,080 Unallocated Items (23,233) (19,553) Eliminations 494 (285) Total $ 69,986 $ 55,410 Expenditures for property, plant and equipment and acquisition of mineral interests Coal Mining $ 14,853 $ 16,830 NAMining 13,203 21,100 Minerals Management 13,388 6,423 Unallocated Items 13,003 208 Total $ 54,447 $ 44,561 Depreciation, depletion and amortization Coal Mining $ 17,074 $ 16,510 NAMining 6,457 4,574 Minerals Management 3,026 1,858 Unallocated Items 259 143 Total $ 26,816 $ 23,085

Unconsolidated Subsidiaries (Ta

Unconsolidated Subsidiaries (Tables)	12 Months Ended
Unconsolidated Subsidiaries (Tables)	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Condensed Financial Statements	Summarized financial information for the unconsolidated subsidiaries is as follows: 2022 2021 Statement of Operations Revenue $ 664,824 $ 764,759 Gross profit $ 47,748 $ 68,076 Income before income taxes $ 57,250 $ 60,865 Net income $ 48,467 $ 53,248 Balance Sheet Current assets $ 214,098 $ 168,669 Non-current assets $ 805,833 $ 900,924 Current liabilities $ 116,701 $ 98,887 Non-current liabilities $ 896,134 $ 963,128

Supplemental Oil and Gas Disc_2

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	Dec. 31, 2022
Extractive Industries [Abstract]
Schedule of Oil and Natural Gas Properties	Aggregate capitalized costs related to oil and gas royalty and mineral interests with applicable accumulated depreciation, depletion and amortization at December 31 are as follows: 2022 2021 Proved developed $ 7,302 $ 3,266 Proved undeveloped 24,134 16,246 Proved reserves 31,436 19,512 Less: accumulated depreciation, depletion and amortization 1,936 868 Net royalty interests in oil and natural gas properties $ 29,500 $ 18,644
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31 based on the reserve report prepared by Haas Engineering, the Company’s independent petroleum engineering firm. All of the Company’s reserves are located in the United States. Net reserves as of December 31, 2022 Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) Proved developed 305,710 408,280 25,907,890 Proved undeveloped 32,570 11,030 1,784,670 Total 338,280 419,310 27,692,560 Net reserves as of December 31, 2021 Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) Proved developed 167,430 282,230 16,617,360 Proved undeveloped 220 90 1,210 Total 167,650 282,320 16,618,570 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases.
Schedule of Change in Estimated Proved Reserves of Oil and Gas Quantities	The following table summarizes changes in proved reserves during the year ended December 31, 2022: Estimated Proved Reserves Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) December 31, 2021 167,650 282,320 16,618,570 Purchases 99,345 35,222 202,314 Extensions and discoveries 121,542 68,167 12,801,109 Revisions of previous estimates (3) (2,504) 95,577 5,405,803 Production (46,571) (61,511) (7,329,985) Other (1,182) (465) (5,251) December 31, 2022 338,280 419,310 27,692,560 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases. (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors.
Schedule of Change in Estimated Proved Undeveloped Reserves of Oil and Gas Quantities	The following table summarizes changes in PUDs during the year ended December 31, 2022: Estimated Proved Undeveloped Reserves Oil (bbl) (1) NGL (bbl) (1) Residue gas (Mcf) (2) December 31, 2021 220 90 1,210 Purchases 21,790 5,104 38,571 Extensions and discoveries 10,780 5,926 1,746,099 Revisions of previous estimates (3) (220) (90) (1,210) December 31, 2022 32,570 11,030 1,784,670 (1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume. (2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases. (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	The following table provides the future net cash flows relating to proved oil and gas reserves based on the standardized measure of discounted cash flows as of December 31, 2022 : Gross Amounts Statutory tax rate Net Amounts Future cash inflows $ 218,982 Future production costs 39,841 Future net cash flows before income tax expense 179,141 21 % 141,521 10% discount to reflect timing of cash flows (62,615) 21 % (49,465) Standardized measure of discounted cash flows $ 116,526 21 % $ 92,056 The following table provides the future net cash flows relating to proved oil and gas reserves based on the standardized measure of discounted cash flows as of December 31, 2021 : Gross Amounts Statutory tax rate Net Amounts Future cash inflows $ 71,400 Future production costs 14,664 Future net cash flows before income tax expense 56,736 21 % 44,821 10% discount to reflect timing of cash flows (19,897) 21 % (15,719) Standardized measure of discounted cash flows $ 36,839 21 % $ 29,102
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The following summarizes the principal sources of change in the standardized measure of discounted future net cash flows during 2022: Gross amounts December 31, 2021 $ 36,839 Purchases 6,236 Extensions and discoveries 54,795 Revisions of previous estimates (3) 18,695 Other (39) December 31, 2022 $ 116,526 (3) Revisions of previous estimates include technical revisions due to changes in commodity prices, historical and projected performance and other factors.

Principles of Consolidation a_2

Principles of Consolidation and Nature of Operations (Narrative) (Details) $ in Thousands			3 Months Ended			12 Months Ended
	May 02, 2022 USD ($)	Sep. 30, 2021 USD ($)	Dec. 31, 2022 USD ($) a	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) a segment	Dec. 31, 2021 USD ($) a
Long-term Purchase Commitment [Line Items]
Number of operating segments \| segment						3
Other contract termination settlements						$ 14,000	$ 10,333
Income from equity method investee						2,194	0
Proceeds from the sale of private company equity units						18,628	0
Acquisition of mineral and royalty interest						$ 11,924	$ 5,331
Gross acreage \| a			13,600			13,600	20,600
Net acreage \| a			880			880	1,800
Mineral and Royalty Interest
Long-term Purchase Commitment [Line Items]
Gross acreage \| a			141,400			141,400
Net acreage \| a			60,800			60,800
Private Equity Funds
Long-term Purchase Commitment [Line Items]
Income from equity method investee				$ 2,200
HLCP
Long-term Purchase Commitment [Line Items]
Proceeds from the sale of private company equity units			$ 18,600
Loss on disposal of equity method investment			1,300
HLCP \| Minimum
Long-term Purchase Commitment [Line Items]
Earn-out payments			0			$ 0
HLCP \| Maximum
Long-term Purchase Commitment [Line Items]
Earn-out payments			$ 13,600			$ 13,600
Coal Mining customer \| Falkirk
Long-term Purchase Commitment [Line Items]
Total gain on contract termination					$ 30,900
Other contract termination settlements	$ 14,000
Fair value gained from contract termination	4,100
Fair value of equity securities without readily determinable fair value, gained as a result of terminated contract	12,800
Investment	$ 5,000
Coal Mining customer \| Bisti
Long-term Purchase Commitment [Line Items]
Other contract termination settlements		$ 10,300

Significant Accounting Polici_3

Significant Accounting Policies (Property Plant and Equipment & Intangible Assets) (Details)	12 Months Ended
	Dec. 31, 2022
Building and building improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment useful life	30 years
Machinery and equipment \| Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment useful life	3 years
Machinery and equipment \| Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment useful life	15 years

Significant Accounting Polici_4

Significant Accounting Policies (Long-Lived Assets) (Details) $ in Millions	Dec. 31, 2022 USD ($)
MLMC
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Long-lived assets	$ 125

Significant Accounting Polici_5

Significant Accounting Policies (Stock-based Compensation and Other) (Details) - Class A Common Stock - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Executives \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares issued during the year under the Company's stock compensation plans (shares)	165,574	138,306
Class A common stock available for issuance under the plan (shares)	396,120
Compensation expense related to share awards	$ 6,400,000	$ 4,100,000
Compensation expense related to share awards, net of tax	$ 5,000,000	3,200,000
Non-employee directors \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Class A common stock available for issuance under the plan (shares)	136,047
Compensation expense related to share awards	$ 1,300,000	1,300,000
Compensation expense related to share awards, net of tax	$ 1,000,000	$ 1,100,000
Non-employee directors \| Restricted stock
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares issued during the year under the Company's stock compensation plans (shares)	30,034	45,223
Amount of directors, annual retainer paid in restricted shares	$ 110,000	$ 105,000
Annual non-employee directors retainer amount	$ 175,000	$ 167,000
Non-employee directors \| Voluntary shares
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares issued during the year under the Company's stock compensation plans (shares)	480	753
Percentage of annual retainer that may be received in shares of Class A stock (percent)	100%
Chairman \| Restricted stock
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Amount of directors, annual retainer paid in restricted shares	$ 150,000	$ 150,000
Annual non-employee directors retainer amount	$ 250,000	$ 250,000
Participant's retirement date \| Executives \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	3 years
Award date \| Executives \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	5 years
Award date \| Non-employee directors \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	10 years
Participants retirement from board of directors \| Non-employee directors \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	5 years
Minimum age of director upon retirement from board \| Non-employee directors \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	70 years
Minimum \| Award date \| Executives \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	3 years
Maximum \| Award date \| Executives \| Share-based Payment Arrangement
Schedule of Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Duration of restrictions on stock assignment, pledges or transfers	10 years

Revenue Recognition (Narrative)

Revenue Recognition (Narrative) (Details) - USD ($)	12 Months Ended
Revenue Recognition (Narrative) (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Performance obligations satisfied in prior period, amount recognized	$ 2,100,000	$ 1,800,000
Opening contract liability	1,000,000	$ 1,400,000
Contract assets recognized	$ 0
Minimum
Disaggregation of Revenue [Line Items]
Primary term of contract	3 years
Maximum
Disaggregation of Revenue [Line Items]
Primary term of contract	5 years

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues	$ 241,719	$ 191,846
Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenues	92,842	80,515
Services transferred over time
Disaggregation of Revenue [Line Items]
Revenues	148,877	111,331
Operating Segments \| Coal Mining customer
Disaggregation of Revenue [Line Items]
Revenues	95,204	82,831
Operating Segments \| NAMining
Disaggregation of Revenue [Line Items]
Revenues	85,664	78,944
Operating Segments \| Minerals Management lessee
Disaggregation of Revenue [Line Items]
Revenues	60,242	31,003
Unallocated Items
Disaggregation of Revenue [Line Items]
Revenues	2,952	4,695
Eliminations
Disaggregation of Revenue [Line Items]
Revenues	$ (2,343)	$ (5,627)

Revenue Recognition (Contract B

Revenue Recognition (Contract Balances) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($)
Trade accounts receivable
Balance at January 1, 2022	$ 0
Balance at December 31, 2022	409
Increase (decrease) in trade accounts receivable	409
Contract asset (current)
Increase (decrease) in contract asset (current)	409
Contract asset (long-term)
Balance at January 1, 2022	5,985
Balance at December 31, 2022	5,985
Increase (decrease) in contract asset (long-term)	0
Contract liability (current)
Balance at January 1, 2022	4,082
Balance at December 31, 2022	833
Increase (decrease) in contract liability (current)	(3,249)
Contract liability (long-term)
Balance at January 1, 2022	1,453
Balance at December 31, 2022	1,709
Increase (decrease) in contract liability (long-term)	256
Trade Accounts Receivable
Trade accounts receivable
Balance at January 1, 2022	25,667
Balance at December 31, 2022	37,940
Increase (decrease) in trade accounts receivable	12,273
Contract asset (current)
Increase (decrease) in contract asset (current)	$ 12,273

Revenue Recognition (Remaining

Revenue Recognition (Remaining Performance Obligations) (Details) $ in Millions	Dec. 31, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 0.8
Remaining performance period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 1.5
Remaining performance period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 0.2
Remaining performance period	1 year

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Coal	$ 27,927	$ 19,352
Mining supplies	43,561	34,733
Total inventories	$ 71,488	$ 54,085

Property, Plant and Equipment_3

Property, Plant and Equipment, Net (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost	$ 382,224	$ 335,633
Less allowances for depreciation, depletion and amortization	164,272	142,466
Property, plant and equipment, net	217,952	193,167
Depreciation, depletion and amortization	23,100	19,500
Coal lands and real estate
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost	60,277	52,011
Mineral interests
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost	31,436	19,512
Plant and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost	$ 290,511	$ 264,110

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Thousands	12 Months Ended
Intangible Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets, Net [Abstract]
Net Balance	$ 28,055	$ 31,774
Amortization of intangible assets	3,719	3,556
Expected annual amortization expense, 2023	3,200
Expected annual amortization expense, 2024	3,100
Expected annual amortization expense, 2025	3,000
Expected annual amortization expense, 2026	3,000
Expected annual amortization expense, 2027	3,000
Coal supply agreement
Finite-Lived Intangible Assets, Net [Abstract]
Gross Carrying Amount	84,200	84,200
Accumulated Amortization	(56,145)	(52,426)
Net Balance	$ 28,055	$ 31,774

Asset Retirement Obligations (A

Asset Retirement Obligations (ARO Activity) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Carrying amount of the asset retirement obligations, balance at beginning of period	$ 43,951	$ 41,732
Liabilities settled during the period	(1,179)	(1,053)
Accretion expense	3,522	3,300
Revision of estimated cash flows	(292)	(28)
Carrying amount of the asset retirement obligations, balance at end of period	46,002	43,951
Operating Segments \| Coal Mining customer
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Carrying amount of the asset retirement obligations, balance at beginning of period	26,898	25,040
Liabilities settled during the period	(223)	(184)
Accretion expense	2,190	1,996
Revision of estimated cash flows	(405)	46
Carrying amount of the asset retirement obligations, balance at end of period	28,460	26,898
Unallocated Items
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Carrying amount of the asset retirement obligations, balance at beginning of period	17,053	16,692
Liabilities settled during the period	(956)	(869)
Accretion expense	1,332	1,304
Revision of estimated cash flows	113	(74)
Carrying amount of the asset retirement obligations, balance at end of period	$ 17,542	$ 17,053

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Details) - Bellaire - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Initial investment amount			$ 5
Fair value of trust assets	$ 9.9	$ 12.3

Current and Long-Term Financi_3

Current and Long-Term Financing (Debt Schedule) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Current portion of borrowings outstanding	$ 3,649	$ 2,527
Long-term portion of borrowings outstanding	16,019	18,183
NACoal
Debt Instrument [Line Items]
Revolving credit agreement	0	4,000
Other debt	19,668	16,710
Total debt outstanding	19,668	20,710
Current portion of borrowings outstanding	3,649	2,527
Long-term portion of borrowings outstanding	16,019	18,183
Total available borrowings, net of limitations, under revolving credit agreement	116,285	120,231
Unused revolving credit agreement	$ 116,285	$ 116,231
Weighted average stated interest rate on total borrowings	3.90%	3.70%

Current and Long-Term Financi_4

Current and Long-Term Financing (Debt Maturity Schedule) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Debt Disclosure [Abstract]
2023	$ 2,873
2024	2,497
2025	1,620
2026	5,955
2027	236
Thereafter	5,692
Long-term debt	$ 18,873	$ 20,400

Current and Long-Term Financi_5

Current and Long-Term Financing (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 15, 2026
Line of Credit Facility [Line Items]
Interest paid	$ 2,000,000	$ 1,600,000
Deferred financing fees		1,800,000
Line of credit facility, average borrowing	2,000,000
Outstanding notes payable	18,873,000	20,400,000
NACoal
Line of Credit Facility [Line Items]
Revolving credit agreement	0	4,000,000
Line of credit facility, remaining borrowing capacity	116,285,000	$ 116,231,000
Secured Debt \| NACoal
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	150,000,000
Revolving credit agreement	0
Line of credit facility, remaining borrowing capacity	116,300,000
Amount of letters of credit outstanding	$ 33,700,000
Line of credit facility, unused capacity, commitment fee percentage	0.34%
Weighted average interest rate	2.54%	4.50%
Fixed charge coverage ratio	1.10
Line of credit facility, availability required to pay dividends	$ 15,000,000
Secured Debt \| NACoal \| Demand Note Payable to Unconsolidated Subsidiary
Line of Credit Facility [Line Items]
Outstanding notes payable	$ 5,700,000	$ 2,600,000
Interest rate	3.36%	0.18%
Secured Debt \| NACoal \| Notes Payable, Maturing At Various Dates Through 2027
Line of Credit Facility [Line Items]
Weighted average interest rate	4.11%
Outstanding notes payable	$ 13,200,000	$ 13,800,000
Secured Debt \| NACoal \| Notes Payable, Maturing December 2026 \| Forecast
Line of Credit Facility [Line Items]
Principal payment due at maturity			$ 4,400,000
Secured Debt \| NACoal \| Maximum
Line of Credit Facility [Line Items]
Maximum debt to EBITDA ratio	2.75
Maximum EBITDA ratio	1.50
Secured Debt \| NACoal \| Minimum
Line of Credit Facility [Line Items]
Minimum interest coverage ratio	4
Maximum EBITDA ratio	1.50
Secured Debt \| NACoal \| Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.23%
Secured Debt \| NACoal \| LIBOR Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.23%

Fair Value Disclosure (Schedule

Fair Value Disclosure (Schedule of Assets and Liabilities) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Quoted prices in active markets for identical assets (level 1)
Assets:
Equity securities	$ 15,534	$ 16,070
Total assets accounted for at fair value on a recurring basis	15,534	16,070
Significant other observable inputs (level 2)
Assets:
Equity securities	0	0
Total assets accounted for at fair value on a recurring basis	0	0
Significant unobservable inputs (level 3)
Assets:
Equity securities	0	0
Total assets accounted for at fair value on a recurring basis	0	0
Estimate of Fair Value Measurement
Assets:
Equity securities	15,534	16,070
Total assets accounted for at fair value on a recurring basis	$ 15,534	$ 16,070

Fair Value Disclosure (Narrativ

Fair Value Disclosure (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Jun. 30, 2022	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loss (gain) on equity securities		$ (283)	$ 3,423
Long-term debt		18,873	20,400
Quoted prices in active markets for identical assets (level 1) \| Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loss (gain) on equity securities		1,900	1,700
Quoted prices in active markets for identical assets (level 1) \| Fair Value, Measurements, Recurring \| Reported Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities cost					$ 2,000
Quoted prices in active markets for identical assets (level 1) \| Fair Value, Measurements, Recurring \| Bellaire
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loss (gain) on equity securities		(2,200)	1,700
Significant unobservable inputs (level 3) \| Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying amount of long-lived lsset after impairment	$ 0
Significant unobservable inputs (level 3) \| Fair Value, Nonrecurring \| Mineral Management
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-cash asset impairment charge	$ 3,900
Significant other observable inputs (level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt fair value		$ 18,100	$ 20,500
Significant other observable inputs (level 2) \| Fair Value, Nonrecurring \| Mineral Management
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value gained from contract termination				$ 4,100

Leases (Schedule of Leased Asse

Leases (Schedule of Leased Assets and Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Assets
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization
Operating lease, assets	$ 6,419	$ 8,911
Finance lease, assets	$ 843	$ 334
Liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other current liabilities	Other current liabilities
Operating lease liabilities, current	$ 1,039	$ 1,463
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Current maturities of long-term debt	Current maturities of long-term debt
Finance lease liabilities, current	$ 776	$ 150
Liabilities, Noncurrent
Operating lease liabilities, noncurrent	$ 7,528	$ 9,733
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Long-term portion of borrowings outstanding	Long-term portion of borrowings outstanding
Finance lease liabilities, noncurrent	$ 19	$ 190
Finance lease, right-of-use asset, accumulated amortization	$ 200	$ 300

Leases (Components of Lease Exp

Leases (Components of Lease Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease cost	$ 1,881	$ 2,122
Amortization of leased assets	128	220
Interest on lease liabilities	13	31
Variable lease expense	534	571
Short-term lease expense	3,434	1,176
Total lease expense	$ 5,990	$ 4,120

Leases (Future Minimum Lease Pa

Leases (Future Minimum Lease Payments) (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Finance Leases
2023	$ 778
2024	12
2025	7
2026	0
2027	0
Subsequent to 2027	0
Total minimum lease payments	797
Amounts representing interest	2
Present value of net minimum lease payments	795
Operating Leases
2023	1,599
2024	1,474
2025	1,283
2026	1,314
2027	1,345
Subsequent to 2027	4,177
Total minimum lease payments	11,192
Amounts representing interest	2,625
Present value of net minimum lease payments	8,567
Total
2023	2,377
2024	1,486
2025	1,290
2026	1,314
2027	1,345
Subsequent to 2027	4,177
Total minimum lease payments	$ 11,989

Leases (Assumptions Used in Acc

Leases (Assumptions Used in Accounting for Leases) (Details)	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease, weighted average remaining lease term (years)	7 years 7 months 28 days	8 years 4 months 17 days
Finance lease, weighted average remaining lease term (years)	1 year 4 months 28 days	2 years 5 months 8 days
Operating lease, weighted average discount rate	7.13%	7.08%
Finance lease, weighted average discount rate	3.11%	4.16%

Leases (Supplemental Cash Flow

Leases (Supplemental Cash Flow Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating cash flows from operating leases	$ 2,097	$ 2,260
Operating cash flows from finance leases	13	31
Financing cash flows from finance leases	$ 183	$ 275

Stockholders' Equity and Earn_3

Stockholders' Equity and Earnings Per Share (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 vote shares	Dec. 31, 2021 shares	Nov. 10, 2021 USD ($)
2021 Stock Repurchase Program
Class of Stock [Line Items]
Authorized amount available for repurchase \| $			$ 20
Treasury stock, shares acquired (in shares)	0	0
Class A Common Stock
Class of Stock [Line Items]
Votes per share \| vote	1
Common stock, shares authorized (in shares)	25,000,000
Treasury stock (in shares)	2,434,769	2,600,661
Class B Common Stock
Class of Stock [Line Items]
Votes per share \| vote	10
Common stock, shares authorized (in shares)	6,756,176

Stockholders' Equity and Earn_4

Stockholders' Equity and Earnings Per Share (Weighted Average Number of Shares Outstanding Reconciliation) (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Equity [Abstract]
Basic weighted average shares outstanding (in shares)	7,312	7,146
Dilutive effect of restricted stock awards (in shares)	61	44
Diluted weighted average shares outstanding (in shares)	7,373	7,190
Earnings per share:
Basic earnings per share (USD per share)	$ 10.14	$ 6.73
Diluted earnings per share (USD per share)	$ 10.06	$ 6.69

Income Taxes (Income Before Inc

Income Taxes (Income Before Income Taxes and Provision for Income Taxes) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Income before income tax provision
Domestic	$ 87,975	$ 57,019
Foreign	(252)	(169)
Income before income tax provision	87,723	56,850
Current income tax provision (benefit):
Federal	20,761	10,870
State	1,328	1,443
Foreign	(53)	(35)
Total current	22,036	12,278
Deferred income tax (benefit) provision:
Federal	(8,887)	(4,449)
State	416	896
Total deferred	(8,471)	(3,553)
Income tax provision	$ 13,565	$ 8,725

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income tax payments	$ 23,400	$ 11,500
Income tax refunds	100	2,600
Income tax provision	13,565	8,725
Income before income taxes	$ 87,723	$ 56,850
Effective income tax rate	15.50%	15.30%
Discrete income tax expense (benefit)	$ 1,500	$ 1,000
Discrete tax benefits, percentage	17.10%	13.50%
Gross unrecognized tax benefits	$ 5,500	$ 6,400
Net benefit in interest and penalties related to uncertain tax positions	100	100
Interest and penalties accrued	$ 300	$ 200

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of the Federal Statutory and Effective Income Tax Rate) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income before income tax provision	$ 87,723	$ 56,850
Statutory taxes at 21.0%	18,422	11,939
State and local income taxes	1,629	1,890
Non-deductible expenses	745	725
Percentage depletion	(4,866)	(6,245)
R&D and other federal credits	(300)	(363)
Settlements and uncertain tax positions	(787)	166
Other, net	(1,278)	613
Income tax provision	$ 13,565	$ 8,725
Effective income tax rate	15.50%	15.30%

Income Taxes (Summary of the To

Income Taxes (Summary of the Total Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Deferred tax assets
Lease liabilities	$ 21,880	$ 24,500
Tax carryforwards	12,398	13,837
Inventories	5,571	4,522
Accrued liabilities	8,176	9,243
Employee benefits	3,086	3,496
Land valuation adjustment	6,261	5,988
Other	6,850	6,527
Total deferred tax assets	64,222	68,113
Less: Valuation allowance	11,809	11,695
Deferred tax assets, net of valuation allowance	52,413	56,418
Deferred tax liabilities
Lease right-of-use assets	21,880	24,500
Depreciation and depletion	19,665	25,851
Partnership investment - development costs	6,069	9,840
Accrued pension benefits	10,921	10,941
Total deferred tax liabilities	58,535	71,132
Net deferred liability	$ (6,122)	$ (14,714)

Income Taxes (Summary of Operat

Income Taxes (Summary of Operating Loss Carryforwards and Tax Credit Carryforwards) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Operating Loss Carryforwards [Line Items]
Net deferred tax asset, net operating loss	$ 12,398	$ 13,837
State and local jurisdiction
Operating Loss Carryforwards [Line Items]
Net deferred tax asset, net operating loss	15,347	17,516
Valuation allowance, net operating loss	$ 14,422	$ 14,694

Income Taxes (Gross Unrecognize

Income Taxes (Gross Unrecognized Tax Benefits) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Reconciliation of Unrecognized Tax Benefits [Roll Forward]
Balance at beginning of period	$ 10,554	$ 10,459
Additions based on tax positions related to prior years	0	95
Decreases based on settlements with tax authorities	(928)	0
Balance at end of period	$ 9,626	$ 10,554

Retirement Benefit Plans (Assum

Retirement Benefit Plans (Assumptions Used in Accounting for Defined Benefit Plans) (Details) - Pension Plan	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Expected long-term rate of return on assets for net periodic benefit cost	7%	7%
Minimum
Defined Benefit Plan Disclosure [Line Items]
Weighted average discount rates for pension benefit obligation	5.36%	2.53%
Weighted average discount rates for net periodic benefit cost	2.53%	2.02%
Maximum
Defined Benefit Plan Disclosure [Line Items]
Weighted average discount rates for pension benefit obligation	5.40%	2.77%
Weighted average discount rates for net periodic benefit cost	2.77%	2.36%

Retirement Benefit Plans (Net P

Retirement Benefit Plans (Net Periodic Benefit Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Interest cost	$ 1,105	$ 1,002
Expected return on plan assets	(2,707)	(2,568)
Amortization of actuarial loss	543	718
Amortization of prior service credit	58	59
Net periodic benefit expense	(1,001)	(789)
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	12	13
Interest cost	38	27
Amortization of actuarial loss	64	19
Amortization of prior service credit	(52)	(54)
Net periodic benefit expense	$ 62	$ 5

Retirement Benefit Plans (Other

Retirement Benefit Plans (Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Loss (Income)) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Current year actuarial gain	$ 1,717	$ (3,793)
Amortization of actuarial loss	(543)	(718)
Amortization of prior service credit	(58)	(59)
Total recognized in other comprehensive loss (income)	1,116	(4,570)
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Current year actuarial gain	(44)	(48)
Amortization of actuarial loss	(64)	(19)
Amortization of prior service credit	52	54
Transfers	0	126
Total recognized in other comprehensive loss (income)	$ (56)	$ 113

Retirement Benefit Plans (Oblig

Retirement Benefit Plans (Obligation and Funded Status) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Amounts recognized in the balance sheets consist of:
Non-current liabilities	$ (5,082)	$ (6,605)
Pension Plan
Change in benefit obligation
Projected benefit obligation at beginning of year	41,663	44,600
Interest cost	1,105	1,002
Actuarial gain	(8,396)	(1,367)
Benefits paid	(2,650)	(2,572)
Projected benefit obligation at end of year	31,722	41,663
Accumulated benefit obligation at end of year	31,722	41,663
Change in plan assets
Fair value of plan assets at beginning of year	44,009	41,099
Actual return on plan assets	(7,405)	4,995
Employer contributions	531	487
Benefits paid	(2,650)	(2,572)
Fair value of plan assets at end of year	34,485	44,009
Funded status at end of year	2,763	2,346
Amounts recognized in the balance sheets consist of:
Non-current assets	6,991	7,806
Current liabilities	(491)	(542)
Non-current liabilities	(3,737)	(4,918)
Amount recognized in the balance sheets	2,763	2,346
Components of accumulated other comprehensive loss consist of:
Actuarial loss	10,682	9,510
Prior service cost	645	703
Deferred taxes	(2,490)	(2,254)
Accumulated other comprehensive (loss) income	8,837	7,959
Other Postretirement Benefits Plan
Change in benefit obligation
Projected benefit obligation at beginning of year	1,877	2,054
Service cost	12	13
Interest cost	38	27
Actuarial gain	(44)	(48)
Benefits paid	(332)	(169)
Projected benefit obligation at end of year	1,551	1,877
Change in plan assets
Funded status at end of year	(1,551)	(1,877)
Amounts recognized in the balance sheets consist of:
Current liabilities	(206)	(190)
Non-current liabilities	(1,345)	(1,687)
Amount recognized in the balance sheets	(1,551)	(1,877)
Components of accumulated other comprehensive loss consist of:
Actuarial loss	412	520
Prior service cost	(56)	(108)
Deferred taxes	(180)	(195)
Accumulated other comprehensive (loss) income	$ 176	$ 217

Retirement Benefit Plans (Sched

Retirement Benefit Plans (Schedule of Expected Benefit Payments) (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
2023	$ 2,731
2024	2,729
2025	2,700
2026	2,691
2027	2,681
2028 - 2032	12,536
Total	26,068
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
2023	211
2024	188
2025	179
2026	183
2027	185
2028 - 2032	654
Total	$ 1,600

Retirement Benefit Plans (Actua

Retirement Benefit Plans (Actual Allocation Percentage and Target Allocation Percentage for the U.S. Pension Plan Assets) (Details) - Pension Plan	Dec. 31, 2022	Dec. 31, 2021
U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation	44.90%	48.70%
Non-U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation	20.50%	19.70%
Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation	34.10%	31.20%
Money market funds
Defined Benefit Plan Disclosure [Line Items]
Actual allocation	0.50%	0.40%
Minimum \| U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	36%
Minimum \| Non-U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	16%
Minimum \| Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	30%
Minimum \| Money market funds
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	0%
Maximum \| U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	54%
Maximum \| Non-U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	24%
Maximum \| Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	40%
Maximum \| Money market funds
Defined Benefit Plan Disclosure [Line Items]
Actual allocation percentage	10%

Retirement Benefit Plans (Fair

Retirement Benefit Plans (Fair Value Hierarchy) (Details) - Pension Plan - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	$ 34,485	$ 44,009	$ 41,099
Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	34,485	44,009
Level 1 \| U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	15,499	21,434
Level 1 \| Non-U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	7,055	8,678
Level 1 \| Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	11,753	13,723
Level 1 \| Money market funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of each major category of U.S. plan assets	$ 178	$ 174

Retirement Benefit Plans (Ass_2

Retirement Benefit Plans (Assumptions Used in Accounting for Postretirement Benefit Plans) (Details) - Other Postretirement Benefits Plan	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted average discount rates for pension benefit obligation	5.29%	2.12%
Weighted average discount rates for net periodic benefit cost	2.12%	1.37%
Health care cost trend rate assumed for next year	6.25%	6.50%
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)		4.50%
Year that the rate reaches the ultimate trend rate	2029	2029
Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50%
Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)	4.75%

Retirement Benefit Plans (Oth_2

Retirement Benefit Plans (Other Changes in Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income) (Details) - Other Postretirement Benefits Plan - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Current year actuarial gain	$ (44)	$ (48)
Amortization of actuarial loss	(64)	(19)
Amortization of prior service credit	52	54
Transfers	0	126
Total recognized in other comprehensive loss (income)	$ (56)	$ 113

Retirement Benefit Plans (Narra

Retirement Benefit Plans (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Retirement Benefits [Abstract]
Defined contribution plan, total costs	$ 3.3	$ 2.9

Business Segments (Concentratio

Business Segments (Concentration Risk) (Details) - Percentage of Consolidated Revenue - Customer concentration risk	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Coal Mining customer \| Coal Mining customer
Segment Reporting Information [Line Items]
Percentage of Consolidated Revenue	39%	43%
NAMining customer \| NAMining customer
Segment Reporting Information [Line Items]
Percentage of Consolidated Revenue	17%	19%

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Thousands	12 Months Ended
Business Segments (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Revenues	$ 241,719	$ 191,846
Operating profit (loss)	69,986	55,410
Expenditures for property, plant and equipment and acquisition of mineral interests	54,447	44,561
Depreciation, depletion and amortization	26,816	23,085
Operating Segments \| Coal Mining customer
Segment Reporting Information [Line Items]
Revenues	95,204	82,831
Operating profit (loss)	38,309	45,784
Expenditures for property, plant and equipment and acquisition of mineral interests	14,853	16,830
Depreciation, depletion and amortization	17,074	16,510
Operating Segments \| NAMining customer
Segment Reporting Information [Line Items]
Revenues	85,664	78,944
Operating profit (loss)	2,202	3,384
Expenditures for property, plant and equipment and acquisition of mineral interests	13,203	21,100
Depreciation, depletion and amortization	6,457	4,574
Operating Segments \| Minerals Management
Segment Reporting Information [Line Items]
Revenues	60,242	31,003
Operating profit (loss)	52,214	26,080
Expenditures for property, plant and equipment and acquisition of mineral interests	13,388	6,423
Depreciation, depletion and amortization	3,026	1,858
Unallocated Items
Segment Reporting Information [Line Items]
Revenues	2,952	4,695
Operating profit (loss)	(23,233)	(19,553)
Expenditures for property, plant and equipment and acquisition of mineral interests	13,003	208
Depreciation, depletion and amortization	259	143
Eliminations
Segment Reporting Information [Line Items]
Revenues	(2,343)	(5,627)
Operating profit (loss)	$ 494	$ (285)

Unconsolidated Subsidiaries (De

Unconsolidated Subsidiaries (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated subsidiaries	$ 14,927	$ 19,090
Income Statement [Abstract]
Revenues	241,719	191,846
Gross profit	67,842	43,452
Income before income taxes	87,723	56,850
Net income	74,158	48,125
Balance Sheet
Current assets	260,407	203,053
Current liabilities	44,270	46,016
NACoal \| Unconsolidated mines
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated subsidiaries	14,900	19,100
Balance Sheet
Dividends from unconsolidated mines	49,000	51,700
NACoal \| Unconsolidated mines
Schedule of Equity Method Investments [Line Items]
Maximum risk of loss	7,100	7,600
NACoal \| Variable Interest Entity, Not Primary Beneficiary \| Unconsolidated mines
Income Statement [Abstract]
Revenues	664,824	764,759
Gross profit	47,748	68,076
Income before income taxes	57,250	60,865
Net income	48,467	53,248
Balance Sheet
Current assets	214,098	168,669
Non-current assets	805,833	900,924
Current liabilities	116,701	98,887
Non-current liabilities	$ 896,134	$ 963,128

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Jones Day
Related Party Transaction [Line Items]
Legal services	$ 1	$ 1.2
Mr. Rankin
Related Party Transaction [Line Items]
Legal services	$ 0.3	$ 0.5

Supplemental Oil and Gas Disc_3

Supplemental Oil and Gas Disclosures (Unaudited) (Oil and Natural Gas Properties) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Extractive Industries [Abstract]
Proved developed	$ 7,302	$ 3,266
Proved undeveloped	24,134	16,246
Proved reserves	31,436	19,512
Less: accumulated depreciation, depletion and amortization	1,936	868
Net royalty interests in oil and natural gas properties	$ 29,500	$ 18,644

Supplemental Oil and Gas Disc_4

Supplemental Oil and Gas Disclosures (Unaudited) (Developed and Undeveloped Reserves) (Details)	Dec. 31, 2022 bbl Mcf	Dec. 31, 2021 bbl Mcf
Oil (bbl)
Reserve Quantities [Line Items]
Proved developed	305,710	167,430
Proved undeveloped	32,570	220
Total	338,280	167,650
NGL (bbl)
Reserve Quantities [Line Items]
Proved developed	408,280	282,230
Proved undeveloped	11,030	90
Total	419,310	282,320
Residue gas (Mcf)
Reserve Quantities [Line Items]
Proved developed \| Mcf	25,907,890	16,617,360
Proved undeveloped \| Mcf	1,784,670	1,210
Total \| Mcf	27,692,560	16,618,570

Supplemental Oil and Gas Disc_5

Supplemental Oil and Gas Disclosures (Unaudited) (Proved Developed Oil And Gas Reserve Quantities) (Details)	12 Months Ended
	Dec. 31, 2022 bbl Mcf
Oil (bbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	167,650
Purchases	99,345
Extensions and discoveries	121,542
Revisions of previous estimates	(2,504)
Production	(46,571)
Other	(1,182)
Ending balance	338,280
NGL (bbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	282,320
Purchases	35,222
Extensions and discoveries	68,167
Revisions of previous estimates	95,577
Production	(61,511)
Other	(465)
Ending balance	419,310
Residue gas (Mcf)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance \| Mcf	16,618,570
Purchases \| Mcf	202,314
Extensions and discoveries \| Mcf	12,801,109
Revisions of previous estimates \| Mcf	5,405,803
Production \| Mcf	(7,329,985)
Other \| Mcf	(5,251)
Ending balance \| Mcf	27,692,560

Supplemental Oil and Gas Disc_6

Supplemental Oil and Gas Disclosures (Unaudited) Proved Undeveloped Oil And Gas Reserve Quantities (Details)	12 Months Ended
	Dec. 31, 2022 bbl Mcf
Oil (bbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	220
Purchases	21,790
Extensions and discoveries	10,780
Revisions of previous estimates	(220)
Ending balance	32,570
NGL (bbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	90
Purchases	5,104
Extensions and discoveries	5,926
Revisions of previous estimates	(90)
Ending balance	11,030
Residue gas (Mcf)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance \| Mcf	1,210
Purchases \| Mcf	38,571
Extensions and discoveries \| Mcf	1,746,099
Revisions of previous estimates \| Mcf	(1,210)
Ending balance \| Mcf	1,784,670

Supplemental Oil and Gas Disc_7

Supplemental Oil and Gas Disclosures (Unaudited) (Narrative) (Details)	Dec. 31, 2022
Extractive Industries [Abstract]
Percentage of proved reserves that are undeveloped	6%

Supplemental Oil and Gas Disc_8

Supplemental Oil and Gas Disclosures (Unaudited) (Future Net Cash Flows From Proved Oil and Gas Reserves) (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Gross Amounts
Future cash inflows	$ 218,982	$ 71,400
Future production costs	39,841	14,664
Future net cash flows before income tax expense	179,141	56,736
10% discount to reflect timing of cash flows	(62,615)	(19,897)
Standardized measure of discounted cash flows	116,526	36,839
Net Amounts
Future net cash flows before income tax expense	141,521	44,821
10% discount to reflect timing of cash flows	(49,465)	(15,719)
Standardized measure of discounted cash flows	$ 92,056	$ 29,102

Supplemental Oil and Gas Disc_9

Supplemental Oil and Gas Disclosures (Unaudited) (Measure of Discounted Future Net Cash Flows (Details)	12 Months Ended
	Dec. 31, 2022 USD ($)
Gross Amounts
Beginning balance	$ 36,839
Purchases	6,236
Extensions and discoveries	54,795
Revisions of previous estimates	18,695
Other	(39)
Ending balance	$ 116,526

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - Deferred tax valuation allowances - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Valuation allowances and reserves [Roll Forward]
Balance at Beginning of Period	$ 11,695	$ 11,549
Charged to Costs and Expenses	114	146
Charged to Other Accounts — Describe	0	0
Deductions — Describe	0	0
Balance at End of Period	$ 11,809	$ 11,695