Form 10-Q - Quarterly report [Sections 13 or 15(d)]

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

☑

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended

June 30, 2024

☐

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the transition period from ____________ to ____________

Commission File Number: 1-16463

____________________________________________

PEABODY ENERGY CORPORATION

(Exact name of registrant as specified in its charter)


Delaware						13-4004153
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

701 Market Street,

St. Louis,

Missouri

63101-1826

(Address of principal executive offices)

(Zip Code)

(314) 342-3400

(Registrant’s telephone number, including area code)

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


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.01 per share	BTU	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:

Large accelerated filer ☑ Accelerated filer ☐

Non-accelerated filer ☐ Smaller reporting company ☐

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

There were 125.9 million shares of the registrant’s common stock (par value of $0.01 per share) outstanding at August 2, 2024.

TABLE OF CONTENTS


			Page
PART I — FINANCIAL INFORMATION
Item 1. Financial Statements			1
Unaudited Condensed Consolidated Statements of Operations			1
Unaudited Condensed Consolidated Statements of Comprehensive Income			2
Condensed Consolidated Balance Sheets			3
Unaudited Condensed Consolidated Statements of Cash Flows			4
Unaudited Condensed Consolidated Statements of Changes in Stockholders’ Equity			6
Notes to Unaudited Condensed Consolidated Financial Statements			7
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			25
Item 3. Quantitative and Qualitative Disclosures About Market Risk			47
Item 4. Controls and Procedures			48
PART II — OTHER INFORMATION
Item 1. Legal Proceedings			48
Item 1A. Risk Factors			48
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			50
Item 4. Mine Safety Disclosures			51
Item 5. Other Information			51
Item 6. Exhibits			51
EXHIBIT INDEX			52
SIGNATURE			53

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions, except per share data)
Revenue	$	1,042.0	$	1,268.8	$	2,025.6	$	2,632.8
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	803.9		862.0		1,618.1		1,708.6
Depreciation, depletion and amortization	82.9		80.6		162.7		156.9
Asset retirement obligation expenses	12.9		15.5		25.8		30.9
Selling and administrative expenses	22.1		21.7		44.1		44.5
Restructuring charges	0.1		2.0		0.2		2.1

Other operating (income) loss:
Net gain on disposals	(7.5)		(5.2)		(9.6)		(7.1)
Asset impairment	—		—		—		2.0
Provision for NARM and Shoal Creek losses	1.9		33.7		3.7		33.7
Shoal Creek insurance recovery	(109.5)		—		(109.5)		—
Loss (income) from equity affiliates	1.3		(2.3)		5.0		(4.1)
Operating profit	233.9		260.8		285.1		665.3
Interest expense, net of capitalized interest	10.7		13.3		25.4		31.7
Net loss on early debt extinguishment	—		2.0		—		8.8
Interest income	(16.8)		(23.1)		(36.0)		(36.2)
Net periodic benefit credit, excluding service cost	(10.2)		(9.7)		(20.3)		(19.4)


Income from continuing operations before income taxes	250.2		278.3		316.0		680.4
Income tax provision	39.4		74.2		59.5		192.2
Income from continuing operations, net of income taxes	210.8		204.1		256.5		488.2
Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)
Net income	209.2		202.8		254.2		485.6

Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Net income attributable to common stockholders	$	199.4	$	179.2	$	239.0	$	447.7

Income from continuing operations:
Basic income per share	$	1.59	$	1.27	$	1.90	$	3.14
Diluted income per share	$	1.43	$	1.16	$	1.72	$	2.85
Net income attributable to common stockholders:
Basic income per share	$	1.58	$	1.26	$	1.88	$	3.12
Diluted income per share	$	1.42	$	1.15	$	1.70	$	2.83

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Net income	$	209.2	$	202.8	$	254.2	$	485.6










Postretirement plans (net of $0.0 tax provisions in each period)	(13.3)		(13.4)		(26.5)		(26.8)




Foreign currency translation adjustment	0.5		(0.4)		(1.4)		(0.6)
Other comprehensive loss, net of income taxes	(12.8)		(13.8)		(27.9)		(27.4)
Comprehensive income	196.4		189.0		226.3		458.2

Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Comprehensive income attributable to common stockholders	$	186.6	$	165.4	$	211.1	$	420.3

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS


	(Unaudited)
	June 30, 2024		December 31, 2023
	(Amounts in millions, except per share data)
ASSETS
Current assets
Cash and cash equivalents	$	621.7	$	969.3

Accounts receivable, net of allowance for credit losses of $0.0 at June 30, 2024 and December 31, 2023	511.6		389.7
Inventories, net	422.1		351.8



Other current assets	296.8		308.9
Total current assets	1,852.2		2,019.7
Property, plant, equipment and mine development, net	3,003.1		2,844.1
Operating lease right-of-use assets	114.1		61.9
Restricted cash and collateral	825.1		957.6
Investments and other assets	83.8		78.8

Total assets	$	5,878.3	$	5,962.1
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current portion of long-term debt	$	14.1	$	13.5
Accounts payable and accrued expenses	729.1		965.5
Total current liabilities	743.2		979.0
Long-term debt, less current portion	323.2		320.7
Deferred income taxes	47.3		28.6
Asset retirement obligations, less current portion	645.9		648.6
Accrued postretirement benefit costs	144.8		148.4
Operating lease liabilities, less current portion	88.2		47.7
Other noncurrent liabilities	170.7		181.6
Total liabilities	2,163.3		2,354.6
Stockholders’ equity

Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of June 30, 2024 and December 31, 2023	—		—
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of June 30, 2024 and December 31, 2023	—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 189.1 shares issued and 125.9 shares outstanding as of June 30, 2024 and 188.6 shares issued and 128.7 shares outstanding as of December 31, 2023	1.9		1.9
Additional paid-in capital	3,987.2		3,983.0
Treasury stock, at cost — 63.2 and 59.9 common shares as of June 30, 2024 and December 31, 2023	(1,825.5)		(1,740.2)
Retained earnings	1,332.5		1,112.7
Accumulated other comprehensive income	161.7		189.6
Peabody Energy Corporation stockholders’ equity	3,657.8		3,547.0
Noncontrolling interests	57.2		60.5
Total stockholders’ equity	3,715.0		3,607.5
Total liabilities and stockholders’ equity	$	5,878.3	$	5,962.1

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Six Months Ended June 30,
	2024		2023
	(Dollars in millions)
Cash Flows From Operating Activities
Net income	$	254.2	$	485.6
Loss from discontinued operations, net of income taxes	2.3		2.6
Income from continuing operations, net of income taxes	256.5		488.2
Adjustments to reconcile income from continuing operations, net of income taxes to net cash provided by operating activities:
Depreciation, depletion and amortization	162.7		156.9
Noncash interest expense, net	3.2		3.3

Deferred income taxes	18.7		65.0
Noncash share-based compensation	4.1		3.4
Asset impairment	—		2.0
Noncash provision for NARM and Shoal Creek losses	—		33.7
Net gain on disposals	(9.6)		(7.1)
Noncash income from port and rail capacity assignment	(0.3)		(9.2)
Net loss on early debt extinguishment	—		8.8
Loss (income) from equity affiliates	5.0		(4.1)

Shoal Creek insurance recovery	(109.5)		—
Foreign currency option contracts	3.3		(0.6)
Changes in current assets and liabilities:
Accounts receivable	(27.3)		149.3
Inventories	(70.4)		(20.8)
Other current assets	18.4		43.4
Accounts payable and accrued expenses	(234.0)		(23.3)
Collateral arrangements	149.6		(116.9)
Asset retirement obligations	(2.7)		3.6
Workers’ compensation obligations	(1.2)		(0.7)
Postretirement benefit obligations	(30.1)		(30.4)
Pension obligations	—		0.7
Other, net	(6.4)		—
Net cash provided by continuing operations	130.0		745.2
Net cash used in discontinued operations	(3.2)		(5.5)
Net cash provided by operating activities	126.8		739.7

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PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - (Continued)

	Six Months Ended June 30,
	2024		2023
	(Dollars in millions)
Cash Flows From Investing Activities
Additions to property, plant, equipment and mine development	(167.0)		(122.3)
Changes in accrued expenses related to capital expenditures	(13.7)		(5.4)
Wards Well acquisition	(143.8)		—
Insurance proceeds attributable to Shoal Creek equipment losses	5.6		—
Proceeds from disposal of assets, net of receivables	15.5		12.0

Contributions to joint ventures	(373.5)		(370.8)
Distributions from joint ventures	360.6		365.8



Other, net	(0.5)		0.7
Net cash used in investing activities	(316.8)		(120.0)
Cash Flows From Financing Activities

Repayments of long-term debt	(4.6)		(4.8)
Payment of debt issuance and other deferred financing costs	(11.1)		(0.3)

Common stock repurchases	(83.1)		(173.0)
Repurchase of employee common stock relinquished for tax withholding	(4.1)		(13.7)
Dividends paid	(19.1)		(10.8)
Distributions to noncontrolling interests	(18.5)		(22.8)

Net cash used in financing activities	(140.5)		(225.4)
Net change in cash, cash equivalents and restricted cash	(330.5)		394.3
Cash, cash equivalents and restricted cash at beginning of period (1)	1,650.2		1,417.6
Cash, cash equivalents and restricted cash at end of period (2)	$	1,319.7	$	1,811.9


(1) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at beginning of period”:
Cash and cash equivalents	$	969.3
Restricted cash included in “Restricted cash and collateral”	680.9
Cash, cash equivalents and restricted cash at beginning of period	$	1,650.2

(2) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at end of period”:
Cash and cash equivalents	$	621.7
Restricted cash included in “Restricted cash and collateral”	698.0
Cash, cash equivalents and restricted cash at end of period	$	1,319.7

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions, except per share data)





Common Stock
Balance, beginning of period	$	1.9	$	1.9	$	1.9	$	1.9





Balance, end of period	1.9		1.9		1.9		1.9
Additional paid-in capital
Balance, beginning of period	3,985.1		3,977.6		3,983.0		3,975.9
Dividend equivalent units on dividends declared	—		0.1		0.1		0.1



Share-based compensation for equity-classified awards	2.1		1.7		4.1		3.4




Balance, end of period	3,987.2		3,979.4		3,987.2		3,979.4
Treasury stock
Balance, beginning of period	(1,824.8)		(1,386.1)		(1,740.2)		(1,372.9)
Common stock repurchases	—		(173.0)		(83.1)		(173.0)
Net change in unsettled common stock repurchases	—		(11.2)		2.6		(11.2)
Excise tax accrued on common stock repurchases	—		(1.6)		(0.7)		(1.6)
Repurchase of employee common stock relinquished for tax withholding	(0.7)		(0.5)		(4.1)		(13.7)
Balance, end of period	(1,825.5)		(1,572.4)		(1,825.5)		(1,572.4)
Retained earnings
Balance, beginning of period	1,142.5		652.4		1,112.7		383.9
Net income attributable to common stockholders	199.4		179.2		239.0		447.7
Dividends declared ($0.075, $0.075, $0.150 and $0.075 per share, respectively)	(9.4)		(10.9)		(19.2)		(10.9)

Balance, end of period	1,332.5		820.7		1,332.5		820.7
Accumulated other comprehensive income
Balance, beginning of period	174.5		228.9		189.6		242.5

Postretirement plans (net of $0.0 tax provisions in each period)	(13.3)		(13.4)		(26.5)		(26.8)
Foreign currency translation adjustment	0.5		(0.4)		(1.4)		(0.6)
Balance, end of period	161.7		215.1		161.7		215.1
Noncontrolling interests
Balance, beginning of period	47.4		55.0		60.5		63.5
Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Distributions to noncontrolling interests	—		—		(18.5)		(22.8)
Balance, end of period	57.2		78.6		57.2		78.6
Total stockholders’ equity	$	3,715.0	$	3,523.3	$	3,715.0	$	3,523.3

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1) Basis of Presentation

The unaudited condensed consolidated financial statements include the accounts of Peabody Energy Corporation (PEC) and its consolidated subsidiaries and affiliates (along with PEC, the Company or Peabody). Interests in subsidiaries controlled by the Company are consolidated with any outside stockholder interests reflected as noncontrolling interests, except when the Company has an undivided interest in a joint venture. In those cases, the Company includes its proportionate share in the assets, liabilities, revenue and expenses of the jointly controlled entities within each applicable line item of the unaudited condensed consolidated financial statements. All intercompany transactions, profits and balances have been eliminated in consolidation.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements and should be read in conjunction with the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023. In the opinion of management, these financial statements reflect all normal, recurring adjustments necessary for a fair presentation. Balance sheet information presented herein as of December 31, 2023 has been derived from the Company’s audited consolidated balance sheet at that date. The Company’s results of operations for the three and six months ended June 30, 2024 are not necessarily indicative of the results that may be expected for future quarters or for the year ending December 31, 2024.

(2) Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented

Newly Adopted Accounting Standards

The Company did not adopt any new accounting standards that had a material impact on its unaudited condensed consolidated financial statements or disclosures.

Accounting Standards Not Yet Implemented

Joint Ventures. In August 2023, Accounting Standards Update (ASU) 2023-05 was issued, which requires joint ventures to recognize and measure the initial contributions of monetary and nonmonetary assets and its net assets at fair value. The Company is required to apply the amendments for joint ventures with a formation date on or after January 1, 2025. A joint venture that was formed before January 1, 2025 may apply the amendments retrospectively.

Segments. In November 2023, ASU 2023-07 was issued, which requires public entities to provide in interim periods all disclosures about a reportable segment’s profit or loss that are currently required annually; disclose significant expense categories and amounts that are easily computable from the management reports that are regularly provided to the chief operating decision maker (CODM); disclose how the CODM uses each reported measure to allocate resources; and disclose the name and title of the position of the individual identified as the CODM. The Company is required to adopt the amendments for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company expects this ASU to only impact its disclosures with no impacts to its consolidated results of operations, cash flows and financial condition.

Income Taxes. In December 2023, ASU 2023-09 was issued, which requires public entities to disclose more information primarily related to the income tax rate reconciliation and income taxes paid. The guidance also eliminates certain existing disclosure requirements related to uncertain tax positions and unrecognized deferred tax liabilities. The Company is required to adopt the amendments for fiscal years beginning after December 15, 2024. The amendments should be applied prospectively, with a retrospective option. Early adoption is permitted. The Company expects this ASU to only impact its disclosures with no impacts to its consolidated results of operations, cash flows and financial condition.

(3) Revenue Recognition

Refer to Note 1. “Summary of Significant Accounting Policies” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023, for the Company’s policies regarding “Revenue” and “Accounts receivable, net.”

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Disaggregation of Revenue

Revenue by product type and market is set forth in the following tables. With respect to its seaborne reporting segments, the Company classifies as “Export” certain revenue from domestically-delivered coal under contracts in which the price is derived on a basis similar to export contracts.


	Three Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	36.9	$	—	$	221.4	$	200.3	$	—	$	458.6
Export	270.6		—		—		—		—		270.6
Total thermal	307.5		—		221.4		200.3		—		729.2
Metallurgical coal

Export	—		294.0		—		—		—		294.0
Total metallurgical	—		294.0		—		—		—		294.0
Other (2)	—		0.3		0.5		1.7		16.3		18.8
Revenue	$	307.5	$	294.3	$	221.9	$	202.0	$	16.3	$	1,042.0


	Three Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	31.9	$	—	$	259.8	$	198.2	$	—	$	489.9
Export	367.5		—		—		—		—		367.5
Total thermal	399.4		—		259.8		198.2		—		857.4
Metallurgical coal

Export	—		371.6		—		—		—		371.6
Total metallurgical	—		371.6		—		—		—		371.6
Other (2)	0.1		0.9		(0.1)		1.7		37.2		39.8
Revenue	$	399.5	$	372.5	$	259.7	$	199.9	$	37.2	$	1,268.8


	Six Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	77.5	$	—	$	475.5	$	378.3	$	—	$	931.3
Export	513.7		—		—		—		—		513.7
Total thermal	591.2		—		475.5		378.3		—		1,445.0
Metallurgical coal

Export	—		538.0		—		—		—		538.0
Total metallurgical	—		538.0		—		—		—		538.0
Other (2)	0.2		3.3		0.5		15.3		23.3		42.6
Revenue	$	591.4	$	541.3	$	476.0	$	393.6	$	23.3	$	2,025.6

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)


	Six Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	69.4	$	—	$	564.8	$	446.1	$	—	$	1,080.3
Export	676.3		—		—		—		—		676.3
Total thermal	745.7		—		564.8		446.1		—		1,756.6
Metallurgical coal

Export	—		658.8		—		—		—		658.8
Total metallurgical	—		658.8		—		—		—		658.8
Other (2)	0.3		2.1		0.2		3.2		211.6		217.4
Revenue	$	746.0	$	660.9	$	565.0	$	449.3	$	211.6	$	2,632.8

(1) Corporate and Other includes the following:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Unrealized gains on derivative contracts related to forecasted sales	$	—	$	40.3	$	—	$	159.0
Realized losses on derivative contracts related to forecasted sales	—		(30.3)		—		(80.9)
Revenue from physical sale of coal (3)	12.1		23.3		14.2		107.8
Trading revenue	—		0.1		—		0.1
Other (2)	4.2		3.8		9.1		25.6
Total Corporate and Other	$	16.3	$	37.2	$	23.3	$	211.6

(2) Includes revenue from arrangements such as customer contract-related payments associated with volume shortfalls; royalties related to coal lease agreements; sales agency commissions; farm income; property and facility rentals; and revenue related to the Company’s assignment of rights to its excess port and rail capacity.

(3) Includes revenue recognized upon the physical sale of coal purchased from the Company’s operating segments and sold to customers through the Company’s coal trading business, including as part of settling certain derivative contracts. Primarily represents the difference between the price contracted with the customer and the price allocated to the operating segment.

Accounts Receivable

“Accounts receivable, net” at June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Trade receivables, net	$	355.8	$	322.3
Miscellaneous receivables, net	155.8		67.4
Accounts receivable, net	$	511.6	$	389.7

None of the above receivables included allowances for credit losses at June 30, 2024 or December 31, 2023. No charges for credit losses were recognized during the three and six months ended June 30, 2024 or 2023.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(4) Inventories

“Inventories, net” as of June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Materials and supplies, net	$	169.2	$	153.0
Raw coal	122.6		105.6
Saleable coal	130.3		93.2
Inventories, net	$	422.1	$	351.8

Materials and supplies inventories, net presented above have been shown net of reserves of $6.6 million and $7.2 million as of June 30, 2024 and December 31, 2023, respectively.

(5) Equity Method Investments

The Company’s equity method investments include its interests in Middlemount Coal Pty Ltd (Middlemount), R3 Renewables LLC (R3) and certain other equity method investments.

The table below summarizes the book value of those investments, which are reported in “Investments and other assets” in the condensed consolidated balance sheets, and the related “Loss (income) from equity affiliates”:


					Loss (Income) from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2024		December 31, 2023		2024		2023		2024		2023
	(Dollars in millions)
Equity method investment related to Middlemount	$	43.0	$	42.5	$	(2.3)	$	(4.1)	$	(1.9)	$	(6.7)
Equity method investment related to R3	8.6		7.1		3.6		1.8		6.9		2.6

Total equity method investments	$	51.6	$	49.6	$	1.3	$	(2.3)	$	5.0	$	(4.1)

The Company contributed $8.4 million and $3.5 million to R3 during the six months ended June 30, 2024 and 2023, respectively.

(6) Derivatives and Fair Value Measurements

Derivatives

From time to time, the Company may utilize various types of derivative instruments to manage its exposure to risks in the normal course of business, including (1) foreign currency exchange rate risk and the variability of cash flows associated with forecasted Australian dollar expenditures made in its Australian mining platform and (2) price risk of fluctuating coal prices related to forecasted sales or purchases of coal, or changes in the fair value of a fixed price physical sales contract. These risk management activities are actively monitored for compliance with the Company’s risk management policies.

On a limited basis, the Company engages in the direct and brokered trading of coal and freight-related contracts. Except those contracts for which the Company has elected to apply a normal purchases and normal sales exception, all derivative coal trading contracts are accounted for at fair value.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Foreign Currency

The Company utilizes options and collars to hedge currency risk associated with anticipated Australian dollar operating expenditures. As of June 30, 2024, the Company held average rate options with an aggregate notional amount of $455.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar operating expenditures over the nine-month period ending March 31, 2025. The instruments entitle the Company to receive payment on the notional amount should the quarterly average Australian dollar-to-U.S. dollar exchange rate exceed amounts ranging from $0.70 to $0.71 over the nine-month period ending March 31, 2025. As of June 30, 2024, the Company also held purchased collars with an aggregate notional amount of $507.0 million Australian dollars related to anticipated Australian dollar operating expenditures during the nine-month period ending March 31, 2025. The purchased collars have a floor and ceiling of approximately $0.59 and $0.72, respectively, whereby the Company will incur a loss on the instruments for rates below the floor and a gain for rates above the ceiling.

Derivative Contracts Related to Forecasted Sales

As of June 30, 2024, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures and forwards.

Financial Trading Contracts

On a limited basis, the Company may enter coal or freight derivative contracts for trading purposes. Such financial contracts may include futures, forwards and options. The Company held nominal financial trading contracts as of June 30, 2024.

Tabular Derivatives Disclosures

The Company has master netting agreements with certain of its counterparties which allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default or termination. Such netting arrangements reduce the Company’s credit exposure related to these counterparties. For classification purposes, the Company records the net fair value of all the positions with a given counterparty as a net asset or liability in the condensed consolidated balance sheets. As of June 30, 2024 and December 31, 2023, the Company had asset derivatives comprised of foreign currency option contracts with a fair value of $2.2 million and $6.2 million, respectively. The net amount of asset derivatives is included in “Other current assets” in the accompanying condensed consolidated balance sheets.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Currently, the Company does not seek cash flow hedge accounting treatment for its derivative financial instruments and thus changes in fair value are reflected in current earnings. The tables below show the amounts of pretax gains and losses related to the Company’s derivatives and their classification within the accompanying unaudited condensed consolidated statements of operations.


		Three Months Ended June 30, 2024
		Total gain recognized in income		Loss realized in income on derivatives		Unrealized gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	0.8	$	(1.6)	$	2.4


Total		$	0.8	$	(1.6)	$	2.4

		Three Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(0.1)	$	(2.9)	$	2.8
Derivative contracts related to forecasted sales	Revenue	10.0		(30.3)		40.3
Financial trading contracts	Revenue	0.1		13.9		(13.8)
Total		$	10.0	$	(19.3)	$	29.3

		Six Months Ended June 30, 2024
		Total loss recognized in income		Loss realized in income on derivatives		Unrealized loss recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.7)	$	(2.4)	$	(3.3)


Total		$	(5.7)	$	(2.4)	$	(3.3)

		Six Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(5.8)	$	0.6
Derivative contracts related to forecasted sales	Revenue	78.1		(80.9)		159.0
Financial trading contracts	Revenue	0.1		31.2		(31.1)
Total		$	73.0	$	(55.5)	$	128.5

The Company classifies the cash effects of its derivatives within the “Cash Flows From Operating Activities” section of the unaudited condensed consolidated statements of cash flows.

Fair Value Measurements

The Company uses a three-level fair value hierarchy that categorizes assets and liabilities measured at fair value based on the observability of the inputs utilized in the valuation. These levels include: Level 1 - inputs are quoted prices in active markets for the identical assets or liabilities; Level 2 - inputs are other than quoted prices included in Level 1 that are directly or indirectly observable through market-corroborated inputs; and Level 3 - inputs are unobservable, or observable but cannot be market-corroborated, requiring the Company to make assumptions about pricing by market participants.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following tables set forth the hierarchy of the Company’s net asset positions for which fair value is measured on a recurring basis.


	June 30, 2024
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	2.2	$	—	$	2.2


Equity securities	0.8		—		—		0.8
Total net assets	$	0.8	$	2.2	$	—	$	3.0

	December 31, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	6.2	$	—	$	6.2


Equity securities	0.4		—		—		0.4
Total net assets	$	0.4	$	6.2	$	—	$	6.6

For Level 1 and 2 financial assets and liabilities, the Company utilizes both direct and indirect observable price quotes, including interest rate yield curves, exchange indices, broker/dealer quotes, published indices, issuer spreads, benchmark securities and other market quotes. In the case of certain debt securities, fair value is provided by a third-party pricing service. Below is a summary of the Company’s valuation techniques for Level 1 and 2 financial assets and liabilities:

•Foreign currency option contracts are valued utilizing inputs obtained in quoted public markets (Level 2) except when credit and non-performance risk is considered to be a significant input, then the Company classifies such contracts as Level 3.

•Derivative contracts related to forecasted sales and financial trading contracts are generally valued based on unadjusted quoted prices in active markets (Level 1) or a valuation that is corroborated by the use of market-based pricing (Level 2) except when credit and non-performance risk is considered to be a significant input (greater than 10% of fair value), then the Company classifies as Level 3.

•Investments in equity securities are based on unadjusted quoted prices in active markets (Level 1).

Other Financial Instruments. The following methods and assumptions were used by the Company in estimating fair values for other financial instruments as of June 30, 2024 and December 31, 2023:

•Cash and cash equivalents, restricted cash, accounts receivable, including those within the Company’s accounts receivable securitization program, margining cash, notes receivable and accounts payable have carrying values which approximate fair value due to the short maturity or the liquid nature of these instruments.

•Long-term debt fair value estimates are based on observed prices for securities when available (Level 2), and otherwise on estimated borrowing rates to discount the cash flows to their present value (Level 3).

Market risk associated with the Company’s fixed-rate long-term debt relates to the potential reduction in the fair value from an increase in interest rates. The fair value of debt, shown below, is principally based on reported market values and estimates based on interest rates, maturities, credit risk, underlying collateral and completed market transactions.


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Total debt at par value	$	344.5	$	342.3
Less: Unamortized debt issuance costs	(7.2)		(8.1)
Net carrying amount	$	337.3	$	334.2

Estimated fair value	$	446.0	$	483.9

The Company’s risk management function, which is independent of the Company’s coal trading function, is responsible for valuation policies and procedures, with oversight from executive management. The fair value of the Company’s coal derivative assets and liabilities reflects adjustments for credit risk. The Company’s exposure to credit risk is substantially with electric utilities, energy marketers, steel producers and nonfinancial trading houses.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

During the six months ended June 30, 2023, the entity in which the Company held a Level 3 investment in equity securities completed a merger transaction and its shares were exchanged for the shares of the newly-combined entity, which are publicly traded. The Company recorded an impairment loss of $2.0 million upon the exchange of shares.

The Company had no transfers between Levels 1, 2 and 3 during the three and six months ended June 30, 2024 and 2023. The Company’s policy is to value all transfers between levels using the beginning of period valuation.

(7) Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of June 30, 2024 and December 31, 2023 is set forth in the table below:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Land and coal interests	$	2,624.0	$	2,475.2
Buildings and improvements	647.7		647.6
Machinery and equipment	1,943.5		1,787.6
Less: Accumulated depreciation, depletion and amortization	(2,212.1)		(2,066.3)
Property, plant, equipment and mine development, net	$	3,003.1	$	2,844.1

At-Risk Assets

The Company identified certain assets with an aggregate carrying value of approximately $214 million at June 30, 2024 in its Other U.S. Thermal segment whose recoverability is most sensitive to customer concentration risk.

(8) Income Taxes

The Company's effective tax rate before remeasurement for the six months ended June 30, 2024 is based on the Company’s estimated full year effective tax rate, comprised of expected statutory tax provision, offset by foreign rate differential and changes in valuation allowance. The Company’s income tax provisions of $39.4 million and $74.2 million for the three months ended June 30, 2024 and 2023, respectively, included tax provisions of $1.9 million and $0.3 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax provisions of $59.5 million and $192.2 million for the six months ended June 30, 2024 and 2023, respectively, included a tax benefit of $3.9 million and a tax provision of $0.7 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s estimated full year pretax income and income tax expense are expected to be primarily generated in Australia.

The Company recognizes interest and penalties related to unrecognized tax benefits in its income tax provision. During both the three and six months ended June 30, 2024, the Company’s net unrecognized tax benefits decreased by $1.3 million and its gross interest and penalties decreased by $6.1 million due to expiration of statutes.

(9) Long-term Debt

The Company’s total indebtedness as of June 30, 2024 and December 31, 2023 consisted of the following:


Debt Instrument (defined below, as applicable)	June 30, 2024		December 31, 2023
	(Dollars in millions)






3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0


Finance lease obligations	24.5		22.3
Less: Debt issuance costs	(7.2)		(8.1)
	337.3		334.2
Less: Current portion of long-term debt	14.1		13.5
Long-term debt	$	323.2	$	320.7

2028 Convertible Notes

On March 1, 2022, through a private offering, the Company issued the 2028 Convertible Notes in the aggregate principal amount of $320.0 million. The 2028 Convertible Notes are senior unsecured obligations of the Company and are governed under an indenture.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The Company used the proceeds of the offering of the 2028 Convertible Notes and available cash to redeem its then-existing senior secured notes, and to pay related premiums, fees and expenses relating to the offering and redemptions. The Company capitalized $11.2 million of debt issuance costs related to the offering, which are being amortized over the terms of the notes.

The 2028 Convertible Notes will mature on March 1, 2028, unless earlier converted, redeemed or repurchased in accordance with their terms. The 2028 Convertible Notes bear interest at a rate of 3.250% per year, payable semi-annually in arrears on March 1 and September 1 of each year.

The initial conversion rate for the 2028 Convertible Notes was 50.3816 shares of the Company’s common stock per $1,000 principal amount of 2028 Convertible Notes, which represented an initial conversion price of approximately $19.85 per share of the Company’s common stock. The terms of the indenture require conversion rate adjustments upon the payment of dividends to holders of the Company’s common stock once such cumulative dividends impact the conversion rate by at least 1%. Effective February 21, 2024, the conversion rate was increased to 51.0440 shares of the Company’s common stock per $1,000 principal amount of 2028 Convertible Notes, which represented an adjusted conversion price of approximately $19.59 per share. Under the applicable conversion rate formula, the $0.075 per share dividend declared on May 2, 2024 and paid on June 5, 2024 yielded a revised conversion rate of 51.2148 shares per $1,000 principal amount of 2028 Convertible Notes, which did not meet the 1% threshold to impact the existing conversion rate of 51.0440. The conversion rate may be impacted prospectively, based upon cumulative dividends paid. The conversion rate is also subject to further adjustment under certain circumstances in accordance with the terms of the indenture.

During the first and second quarters of 2024, the Company’s reported common stock prices did not prompt the conversion feature of the 2028 Convertible Notes. As a result, the 2028 Convertible Notes were not convertible at the option of the holders during the second quarter of 2024, and will not be similarly convertible during the third quarter of 2024.

As of June 30, 2024, the if-converted value of the 2028 Convertible Notes exceeded the principal amount by $41.3 million.

Revolving Credit Facility

The Company established a new revolving credit facility with a maximum aggregate principal amount of $320.0 million in revolving commitments by entering into a credit agreement, dated as of January 18, 2024 (the 2024 Credit Agreement), by and among the Company, as borrower, certain subsidiaries of the Company party thereto, PNC Bank, National Association, as administrative agent, and the lenders party thereto. The Company paid aggregate debt issuance costs of $9.7 million.

The revolving commitments and any related loans, if applicable (any such loans, the Revolving Loans), established by the 2024 Credit Agreement terminate or mature, as applicable, on January 18, 2028, subject to certain conditions relating to the Company’s outstanding 2028 Convertible Notes. The Revolving Loans bear interest at a secured overnight financing rate (SOFR) plus an applicable margin ranging from 3.50% to 4.25%, depending on the Company’s total net leverage ratio (as defined under the 2024 Credit Agreement) or a base rate plus an applicable margin ranging from 2.50% to 3.25%, at the Company’s option. Letters of credit issued under the 2024 Credit Agreement incur a combined fee equal to an applicable margin ranging from 3.50% to 4.25% plus a fronting fee equal to 0.125% per annum. Unused capacity under the 2024 Credit Agreement bears a commitment fee of 0.50% per annum.

As of June 30, 2024, the 2024 Credit Agreement had only been utilized for letters of credit, including $98.0 million outstanding as of June 30, 2024. These letters of credit support the Company’s reclamation bonding requirements, lease obligations, insurance policies and various other performance guarantees as further described in Note 12. “Financial Instruments and Other Guarantees.” Availability under the 2024 Credit Agreement was $222.0 million at June 30, 2024.

The 2024 Credit Agreement contains customary covenants that, among other things and subject to certain exceptions (including compliance with financial ratios), may limit the Company and its subsidiaries’ ability to incur additional indebtedness, make certain restricted payments or investments, sell or otherwise dispose of assets, enter into transactions with affiliates, create or incur liens, and merge, consolidate or sell all or substantially all of their assets. The 2024 Credit Agreement is secured by substantially all assets of the Company and its U.S. subsidiaries, as well as a pledge of two Australian subsidiaries.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Interest Charges

The following table presents the components of the Company’s interest expense related to its indebtedness and financial assurance instruments such as surety bonds and letters of credit. Additionally, the table sets forth the amount of cash paid for interest, net of capitalized interest and the amount of non-cash interest expense primarily related to the amortization of debt issuance costs.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
2028 Convertible Notes	$	2.6	$	2.6	$	5.2	$	5.2
Finance lease obligations	0.5		0.4		0.9		0.9
Financial assurance instruments	6.1		8.0		14.9		20.0
Amortization of debt issuance costs	2.0		0.7		3.2		2.3
Capitalized interest	(1.7)		—		(1.7)		—
Other	1.2		1.6		2.9		3.3
Interest expense, net of capitalized interest	$	10.7	$	13.3	$	25.4	$	31.7

Cash paid for interest, net of capitalized interest	$	12.6	$	22.9	$	24.1	$	41.9
Non-cash interest expense	$	1.9	$	1.7	$	3.2	$	3.3

Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2024.

(10) Pension and Postretirement Benefit Costs

The components of net periodic pension and postretirement benefit costs, excluding the service cost for benefits earned, are included in “Net periodic benefit credit, excluding service cost” in the unaudited condensed consolidated statements of operations.

Net periodic pension cost included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)

Interest cost on projected benefit obligation	$	1.6	$	7.4	$	3.2	$	14.8
Expected return on plan assets	(1.2)		(6.6)		(2.4)		(13.2)

Net periodic pension cost	$	0.4	$	0.8	$	0.8	$	1.6

At January 1, 2023, the Company had two qualified pension plans. During the year ended December 31, 2023, the Company settled its pension obligation for one of its qualified plans. Refer to Note 14. “Pension and Savings Plans” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023, for information regarding the settlement of the plan’s obligation.

Annual contributions to the remaining qualified plan are made in accordance with minimum funding standards and the Company’s agreement with the Pension Benefit Guaranty Corporation. Funding decisions also consider certain funded status thresholds defined by the Pension Protection Act of 2006. As of June 30, 2024, the Company’s remaining qualified plan was expected to be at or above the Pension Protection Act thresholds. The Company is not required to make any cash contributions to its remaining qualified pension plan in 2024 based on minimum funding requirements and does not expect to make any discretionary cash contributions in 2024.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Net periodic postretirement benefit credit included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Service cost for benefits earned	$	0.1	$	0.2	$	0.2	$	0.3
Interest cost on accumulated postretirement benefit obligation	2.3		2.5		4.6		5.0
Expected return on plan assets	(0.1)		(0.2)		(0.2)		(0.3)
Amortization of prior service credit	(13.3)		(13.4)		(26.5)		(26.8)

Net periodic postretirement benefit credit	$	(11.0)	$	(10.9)	$	(21.9)	$	(21.8)

The Company has established a Voluntary Employees’ Beneficiary Association (VEBA) trust to pre-fund a portion of benefits for non-represented retirees. The Company does not expect to make any discretionary contributions to the VEBA trust in 2024 and plans to utilize a portion of VEBA assets to make certain benefit payments.

(11) Earnings per Share (EPS)

Basic EPS is computed based on the weighted average number of shares of common stock outstanding during the period. Diluted EPS is computed based on the weighted average number of shares of common stock plus the effect of dilutive potential common shares outstanding. As such, the Company includes the 2028 Convertible Notes and share-based compensation awards in its potentially dilutive securities. Generally, dilutive securities are not included in the computation of loss per share when a company reports a net loss from continuing operations as the impact would be anti-dilutive.

For all but performance units, the potentially dilutive impact of the Company’s share-based compensation awards is determined using the treasury stock method. Under the treasury stock method, awards are treated as if they had been exercised with any proceeds used to repurchase common stock at the average market price during the period. Any incremental difference between the assumed number of shares issued and purchased is included in the diluted share computation. For performance units, their contingent features result in an assessment for any potentially dilutive common stock by using the end of the reporting period as if it were the end of the contingency period for all units granted.

A conversion of the 2028 Convertible Notes may result in payment in the Company’s common stock. For diluted EPS purposes, the potentially dilutive common stock is assumed to have been converted at the beginning of the period (or at the time of issuance, if later). In periods where the potentially dilutive common stock is included in the computation of diluted EPS, the numerator will be adjusted to add back tax adjusted interest expense, which includes the amortization of debt issuance costs, related to the convertible debt.

The computation of diluted EPS excluded aggregate share-based compensation awards of less than 0.1 million for the three and six months ended June 30, 2024 and 2023 because to do so would have been anti-dilutive for those periods. Because the potential dilutive impact of such share-based compensation awards is calculated under the treasury stock method, anti-dilution generally occurs when the exercise prices or unrecognized compensation cost per share of such awards are higher than the Company’s average stock price during the applicable period. Anti-dilution also occurs when a company reports a net loss from continuing operations, and the dilutive impact of all share-based compensation awards are excluded accordingly.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following illustrates the earnings allocation method utilized in the calculation of basic and diluted EPS.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	201.0		180.5		241.3		450.3


Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)


Net income attributable to common stockholders	$	199.4	$	179.2	$	239.0	$	447.7

Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.0		3.5		6.1		6.1
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	204.0		184.0		247.4		456.4
Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)
Net income attributable to common stockholders	$	202.4	$	182.7	$	245.1	$	453.8

EPS denominator:
Weighted average shares outstanding — basic	126.0		142.3		127.0		143.4
Dilutive impact of share-based compensation awards	0.5		0.6		0.5		0.7
Dilutive impact of 2028 Convertible Notes	16.3		16.1		16.3		16.1
Weighted average shares outstanding — diluted	142.8		159.0		143.8		160.2

Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.59	$	1.27	$	1.90	$	3.14
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.58	$	1.26	$	1.88	$	3.12

Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.43	$	1.16	$	1.72	$	2.85
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.42	$	1.15	$	1.70	$	2.83

(12) Financial Instruments and Other Guarantees

In the normal course of business, the Company is a party to various guarantees and financial instruments that carry off-balance-sheet risk and are not reflected in the accompanying condensed consolidated balance sheets. Such financial instruments provide support for the Company’s reclamation bonding requirements, lease obligations, insurance policies and various other performance guarantees. The Company periodically evaluates the instruments for on-balance-sheet treatment based on the amount of exposure under the instrument and the likelihood of required performance. The Company does not expect any material losses to result from these guarantees or off-balance-sheet instruments in excess of liabilities provided for in the accompanying condensed consolidated balance sheets.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following table summarizes the Company’s financial instruments that carry off-balance-sheet risk.


	June 30, 2024
	Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	934.0	$	108.1	$	1,042.1
Letters of credit (2)	52.5		101.7		154.2
	986.5		209.8		1,196.3
Less: Letters of credit in support of surety bonds (3)	(52.5)		(14.5)		(67.0)
Obligations supported, net	$	934.0	$	195.3	$	1,129.3

(1) Instruments support obligations related to pension and health care plans, workers’ compensation, property and casualty insurance, customer and vendor contracts and certain restoration ancillary to prior mining activities.

(2) Amounts do not include cash-collateralized letters of credit.

(3) Certain letters of credit serve as collateral for surety bonds at the request of surety bond providers.

Surety Agreement Amendment and Collateral Requirements

In April 2023, the Company amended its existing agreement with the providers of its surety bond portfolio, dated November 6, 2020. Under the April 2023 amendment, the Company and its surety providers agreed to a maximum aggregate collateral amount of $721.8 million based upon bonding levels at the effective date of the amendment. This maximum collateral amount will vary prospectively as bonding levels increase or decrease. The amendment extended the agreement through December 31, 2026. In order to maintain the maximum collateral agreement, the Company must remain compliant with a minimum liquidity test and a maximum net leverage ratio, as measured each quarter. The minimum liquidity test requires the Company to maintain liquidity at the greater of $400 million or the difference between the penal sum of all surety bonds and the amount of collateral posted in favor of surety providers, which was $508.6 million at June 30, 2024. The Company must also maintain a maximum net leverage ratio of 1.5 to 1.0, where the numerator consists of its funded debt, net of cash, and the denominator consists of its Adjusted EBITDA for the trailing twelve months. For purposes of calculating the ratio, only 50% of the outstanding principal amount of the Company’s 2028 Convertible Notes is deemed to be funded debt. The Company’s ability to pay dividends and make share repurchases is also subject to the quarterly minimum liquidity test. The Company is in compliance with such requirements at June 30, 2024.

To fund the maximum collateral amount, the Company deposited $566.3 million into trust accounts for the benefit of certain surety providers on March 31, 2023. The remainder was comprised of $140.5 million of existing cash-collateralized letters of credit and $15.0 million already held on behalf of a surety provider. The amendment became effective on April 14, 2023, when the Company terminated a then-existing credit agreement which, as amended, provided for $237.2 million of capacity for irrevocable standby letters of credit (LC Facility).

LC Facility

The now-terminated LC Facility had an original capacity of $324.0 million and was subsequently amended at various dates to reduce its capacity and effect certain other changes, including in February 2023 to reduce capacity by $65.0 million, accelerate the expiration date to December 31, 2023 from December 31, 2024, and eliminate the prepayment premium due upon any reduction of commitments thereunder prior to July 29, 2023. The Company recorded early debt extinguishment losses of $8.8 million during the six months ended June 30, 2023, primarily as a result of the February 2023 amendment and subsequent termination.

Prior to its termination, undrawn letters of credit under the LC Facility bore interest at 6.00% per annum and unused commitments were subject to a 0.50% per annum commitment fee.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Accounts Receivable Securitization

In 2017, the Company entered into the Sixth Amended and Restated Receivables Purchase Agreement, as amended from time to time (the Receivables Purchase Agreement). The receivables securitization program authorized under the agreement (Securitization Program) is subject to customary events of default. The Receivables Purchase Agreement was amended in February 2023 to increase the available funding capacity from $175.0 million to $225.0 million and adjust the relevant interest rate for borrowings to a SOFR plus an applicable margin. Such funding is accounted for as a secured borrowing, limited to the availability of eligible receivables, and may be secured by a combination of collateral and the trade receivables underlying the program. Funding capacity under the Securitization Program may also be utilized for letters of credit in support of other obligations, which has been the Company’s primary utilization.

Borrowings under the Securitization Program bear interest at a SOFR plus 2.1% per annum and remain outstanding throughout the term of the agreement, subject to the Company maintaining sufficient eligible receivables.

At June 30, 2024, the Company had no outstanding borrowings and $56.2 million of letters of credit outstanding under the Securitization Program. Availability under the Securitization Program, which is adjusted for certain ineligible receivables, was $97.1 million at June 30, 2024. The Company was not required to post cash collateral under the Securitization Program at June 30, 2024.

The Company incurred interest and fees associated with the Securitization Program of $0.6 million and $0.8 million during the three months ended June 30, 2024 and 2023, respectively, and $1.4 million and $1.9 million during the six months ended June 30, 2024 and 2023, respectively, which have been recorded as “Interest expense, net of capitalized interest” in the accompanying unaudited condensed consolidated statements of operations.

Credit Support Facilities

In February 2022, the Company entered into an agreement which provides up to $250.0 million of capacity for irrevocable standby letters of credit, primarily to support reclamation bonding requirements. The agreement requires the Company to provide cash collateral at a level of 103% of the aggregate amount of letters of credit outstanding under the arrangement (limited to $5.0 million total excess collateralization). Outstanding letters of credit bear a fixed fee in the amount of 0.75% per annum. The Company receives a variable deposit rate on the amount of cash collateral posted in support of letters of credit. The agreement has an initial expiration date of December 31, 2025. At June 30, 2024, letters of credit of $116.6 million were outstanding under the agreement, which were collateralized by cash of $120.1 million.

In December 2023, the Company established cash-backed bank guarantee facilities, primarily to support Australian reclamation bonding requirements. During the six months ended June 30, 2024, the Company capitalized $1.4 million of debt issuance costs related to these bank guarantee facilities. The Company receives a variable deposit rate on the amount of cash collateral posted in support of the bank guarantee facilities, which mature at various dates between 2026 and 2029. At June 30, 2024, the bank guarantee facilities were backed by cash of $179.5 million.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Restricted Cash and Collateral

The following table summarizes the Company’s “Restricted cash and collateral” in the accompanying condensed consolidated balance sheets. Restricted cash balances are held in controlled accounts with minimum balance requirements; withdrawals are subject to the approval of account beneficiaries, such as the Company’s surety providers, who have perfected security interests in the funds. The Company’s other cash collateral generally includes deposits held by regulatory authorities or financial institutions over which the Company has no control or ability to access.


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	398.4	$	444.0
Credit support facilities (2)	299.6		236.9
	698.0		680.9
Other cash collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	127.1		276.7


	127.1		276.7
Restricted cash and collateral	$	825.1	$	957.6

(1) Restricted cash balances are combined with unrestricted cash and cash equivalents in the accompanying unaudited condensed consolidated statements of cash flows; changes between unrestricted cash and cash equivalents and restricted cash balances are thus not reflected in the operating, investing or financing activities therein. Changes in other cash collateral balances are reflected as operating activities therein.

(2) Surety trust accounts, the funding for collateralized letters of credit and cash supporting the bank guarantee facilities are comprised of highly liquid investments with original maturities of three months or less; interest and other earnings on such funds accrue to the Company.

(13) Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of June 30, 2024, purchase commitments for capital expenditures were $90.9 million, all of which is obligated within the next two years, with $83.7 million obligated within the next 12 months.

There were no other material changes to the Company’s commitments from the information provided in Note 21. “Commitments and Contingencies” to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023.

Contingencies

From time to time, the Company or its subsidiaries are involved in legal proceedings arising in the ordinary course of business or related to indemnities or historical operations. The Company believes it has recorded adequate reserves for these liabilities. The Company discusses its significant legal proceedings below, including ongoing proceedings and those that impacted the Company’s consolidated results of operations for the periods presented.

Litigation and Matters Relating to Continuing Operations

Metropolitan Mine Stormwater Discharge. Significantly high rainfall in New South Wales, including unprecedented rain totals at the Metropolitan Mine site resulted in stormwater being discharged from the mine site on several occasions in 2021 and 2022. On September 6, 2023, the Environment Protection Authority commenced a prosecution for five breaches of the Protection of the Environment Operations Act 1997 relating to the stormwater discharges. On March 15, 2024, the Company pled guilty to two of the charges related to water pollution, and two charges related to a failure to adequately maintain plant and equipment were consolidated into one charge to which the Company also pled guilty. No plea has been entered for the remaining charge that has been held over to a sentencing hearing that is scheduled for November 2024. Penalties will be determined at that sentencing hearing. During the six months ended June 30, 2024, the Company recorded an immaterial provision to establish a current liability that the Company believes is probable and reasonably estimable.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Oregon Climate Change Lawsuit. On July 20, 2023, Peabody Energy was served with a summons issued on behalf of Multnomah County, Oregon. The complaint sought damages from the Company and other major energy producers for allegedly causing an “extreme heat event” in Multnomah County in late June and early July 2021. The causes of action, pursuant to Oregon state law, included a failure to warn, false or misleading advertisement and public nuisance. In July 2024, Peabody was dismissed from this case, without prejudice.

Other

At times, the Company becomes a party to other disputes, including those related to contract miner performance, claims, lawsuits, arbitration proceedings, regulatory investigations and administrative procedures in the ordinary course of business in the U.S., Australia and other countries where the Company does business. Based on current information, the Company believes that such other pending or threatened proceedings are likely to be resolved without a material adverse effect on its consolidated financial condition, results of operations or cash flows. The Company reassesses the probability and estimability of contingent losses as new information becomes available.

(14) Segment Information

The Company reports its results of operations primarily through the following reportable segments: Seaborne Thermal, Seaborne Metallurgical, Powder River Basin, Other U.S. Thermal and Corporate and Other. The Company’s CODM, defined as its Chief Executive Officer, uses Adjusted EBITDA as the primary metric to measure the segments’ operating performance and allocate resources.

Adjusted EBITDA is a non-GAAP financial measure defined as income from continuing operations before deducting net interest expense, income taxes, asset retirement obligation expenses and depreciation, depletion and amortization. Adjusted EBITDA is also adjusted for the discrete items that management excluded in analyzing the segments’ operating performance, as displayed in the reconciliation below. Management believes this non-GAAP performance measure is also used by investors to measure the Company’s operating performance. Adjusted EBITDA is not intended to serve as an alternative to U.S. GAAP measures of performance and may not be comparable to similarly-titled measures presented by other companies.

Reportable segment results were as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	307.5	$	399.5	$	591.4	$	746.0
Seaborne Metallurgical	294.3		372.5		541.3		660.9
Powder River Basin	221.9		259.7		476.0		565.0
Other U.S. Thermal	202.0		199.9		393.6		449.3
Corporate and Other	16.3		37.2		23.3		211.6
Total	$	1,042.0	$	1,268.8	$	2,025.6	$	2,632.8

Adjusted EBITDA:
Seaborne Thermal	$	104.4	$	197.5	$	198.2	$	361.5


Seaborne Metallurgical	143.6		102.5		191.9		193.3
Powder River Basin	17.8		26.2		34.2		62.0
Other U.S. Thermal	35.4		51.9		81.9		116.1
Corporate and Other	8.5		(19.9)		(36.0)		15.9
Total	$	309.7	$	358.2	$	470.2	$	748.8

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

A reconciliation of consolidated income from continuing operations, net of income taxes to Adjusted EBITDA follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Depreciation, depletion and amortization	82.9		80.6		162.7		156.9
Asset retirement obligation expenses	12.9		15.5		25.8		30.9
Restructuring charges	0.1		2.0		0.2		2.1

Asset impairment	—		—		—		2.0
Provision for NARM and Shoal Creek losses	1.9		33.7		3.7		33.7
Shoal Creek insurance recovery - property damage	(28.7)		—		(28.7)		—
Changes in amortization of basis difference related to equity affiliates	(0.3)		(0.4)		(0.7)		(0.7)
Interest expense, net of capitalized interest	10.7		13.3		25.4		31.7
Net loss on early debt extinguishment	—		2.0		—		8.8
Interest income	(16.8)		(23.1)		(36.0)		(36.2)

Unrealized gains on derivative contracts related to forecasted sales	—		(40.3)		—		(159.0)
Unrealized (gains) losses on foreign currency option contracts	(2.4)		(2.8)		3.3		(0.6)

Take-or-pay contract-based intangible recognition	(0.8)		(0.6)		(1.5)		(1.2)
Income tax provision	39.4		74.2		59.5		192.2
Adjusted EBITDA	$	309.7	$	358.2	$	470.2	$	748.8

(15) Other Events

Wards Well Acquisition

The Company entered into a definitive agreement dated October 26, 2023, to acquire the southern part of the Wards Well tenements (Wards Well) which are adjacent to the Company’s Centurion Mine in Queensland, Australia. The acquisition, which was accounted for as an asset acquisition, was completed on April 16, 2024. The acquired asset was measured at the cost of the acquisition based on the total consideration, allocated on the basis of relative fair value. The total consideration of $153.4 million, consisting of cash consideration of $134.4 million, cash transaction costs of $9.4 million and the non-cash settlement of existing receivables with the acquiree of $9.6 million, was recorded in “Property, plant, equipment and mine development, net” in the condensed consolidated balance sheets as of June 30, 2024.

The agreement also includes an initial contingent royalty of up to $200 million. The royalty will only be payable once the Company has recovered its investment and development costs of Wards Well and if the average sales price achieved exceeds certain thresholds. No royalty is payable if the Company does not commence mining Wards Well. The Company will adjust the cost basis of the assets acquired if and when the contingent royalty is paid or becomes payable.

Share Repurchases

During the six months ended June 30, 2024, the Company repurchased approximately 3.2 million shares of its common stock for $80.5 million, including commission fees. No shares were repurchased during the three months ended June 30, 2024. The Company had accrued excise taxes of $4.0 million related to share repurchases, which were unpaid at June 30, 2024. The Company includes commission fees and excise taxes, as incurred, with the cost of treasury stock. At June 30, 2024, $569.6 million remained available under its share repurchase program.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

North Antelope Rochelle Mine Tornado

On June 23, 2023, the Company’s North Antelope Rochelle Mine sustained damage from a tornado which led to a temporary suspension of operations. The mine resumed operations on June 25, 2023. During the three and six months ended June 30, 2023, the Company recorded a provision for loss of $5.0 million related to the tornado damage, which included $4.0 million for materials and supplies inventories and $1.0 million for buildings and equipment. During the three and six months ended June 30, 2024, the Company recorded $1.9 million and $3.7 million, respectively, for incremental repair costs related to the tornado damage.

Shoal Creek

On March 29, 2023, the Company’s Shoal Creek Mine experienced a fire involving void fill material utilized to stabilize the roof structure of the mine. On June 20, 2023, the Company announced that the Shoal Creek Mine, in coordination with the Mine Safety and Health Administration, had safely completed localized sealing of the affected area of the mine. During the three and six months ended June 30, 2023, the Company recorded a provision for loss of $28.7 million related to the fire, which included $17.8 million related to longwall development and other costs and $10.9 million for equipment deemed inoperable within the affected area of the mine.

In October 2023, the Company filed an insurance claim against applicable insurance policies with combined business interruption and property loss limits of $125 million above a $50 million deductible. During June 2024, the Company reached a settlement with its insurers and various re-insurers and recognized a $109.5 million insurance recovery which the Company included in its results of operations for the three and six months ended June 30, 2024.

During the six months ended June 30, 2024, the Company collected $5.6 million of the insurance recovery. Since this portion of the recovery related to equipment damage for which the Company previously recognized the provision for loss, the Company has classified the amount within the “Cash Flows From Investing Activities” section of the unaudited condensed consolidated statements of cash flows. The remaining $103.9 million of the insurance recovery was recorded as a receivable within “Accounts receivable, net” in the condensed consolidated balance sheets as of June 30, 2024.

Port and Rail Capacity Assignment

During the six months ended June 30, 2023, the Company entered into an agreement to assign the right to its excess port and rail capacity related to its Centurion Mine to an unrelated party in exchange for $30.0 million Australian dollars. Half of such amount was received by the Company upon entry into the agreement, and half was payable in June 2024, subject to certain conditions. In connection with the transaction, the Company recorded revenue of $19.2 million during the six months ended June 30, 2023. In association with the completion of the Wards Well acquisition described above, the remaining receivable was settled as part of the consideration on April 16, 2024.

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

As used in this report, the terms “Peabody” or “the Company” refer to Peabody Energy Corporation or its applicable subsidiary or subsidiaries. Unless otherwise noted herein, disclosures in this Quarterly Report on Form 10-Q relate only to the Company’s continuing operations.

When used in this filing, the term “ton” refers to short or net tons, equal to 2,000 pounds (907.18 kilograms), while “tonne” refers to metric tons, equal to 2,204.62 pounds (1,000 kilograms).

Cautionary Notice Regarding Forward-Looking Statements

This report includes statements of Peabody’s expectations, intentions, plans and beliefs that constitute “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and are intended to come within the safe harbor protection provided by those sections. These statements relate to future events or Peabody’s future financial performance. The Company uses words such as “anticipate,” “believe,” “expect,” “may,” “forecast,” “project,” “should,” “estimate,” “plan,” “outlook,” “target,” “likely,” “will,” “to be” or other similar words to identify forward-looking statements.

Without limiting the foregoing, all statements relating to Peabody’s future operating results, anticipated capital expenditures, future cash flows and borrowings, and sources of funding are forward-looking statements and speak only as of the date of this report. These forward-looking statements are based on numerous assumptions that Peabody believes are reasonable, but are subject to a wide range of uncertainties and business risks, and actual results may differ materially from those discussed in these statements. These factors are difficult to accurately predict and may be beyond the Company’s control.

When considering these forward-looking statements, you should keep in mind the cautionary statements in this document and in the Company’s other Securities and Exchange Commission (SEC) filings, including, but not limited to, the more detailed discussion of these factors and other factors that could affect its results contained in Item 1A. “Risk Factors” of Part II of this Quarterly Report on Form 10-Q and Item 1A. “Risk Factors” and Item 3. “Legal Proceedings” of Part I of its Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 23, 2024. These forward-looking statements speak only as of the date on which such statements were made, and the Company undertakes no obligation to update these statements except as required by federal securities laws.

Non-GAAP Financial Measures

The following discussion of the Company’s results of operations includes references to and analysis of Adjusted EBITDA and Total Reporting Segment Costs, which are financial measures not recognized in accordance with U.S. generally accepted accounting principles (U.S. GAAP). Adjusted EBITDA is used by the chief operating decision maker as the primary metric to measure each of the segments’ operating performance and allocate resources. Total Reporting Segment Costs is also used by management as a component of a metric to measure each of its segments’ operating performance.

Also included in the following discussion of the Company’s results of operations are references to Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton for each reporting segment. These metrics are used by management to measure each of its reporting segments’ operating performance. Management believes Costs per Ton and Adjusted EBITDA Margin per Ton best reflect controllable costs and operating results at the reporting segment level. The Company considers all measures reported on a per ton basis to be operating/statistical measures; however, the Company includes reconciliations of the related non-GAAP financial measures (Adjusted EBITDA and Total Reporting Segment Costs) in the “Reconciliation of Non-GAAP Financial Measures” section contained within this Item 2.

In its discussion of liquidity and capital resources, the Company includes references to Available Free Cash Flow (AFCF) which is also a non-GAAP financial measure. AFCF is used by management as a measure of its ability to generate excess cash flow from its business operations.

The Company believes non-GAAP performance measures are used by investors to measure its operating performance. These measures are not intended to serve as alternatives to U.S. GAAP measures of performance and may not be comparable to similarly-titled measures presented by other companies. Refer to the “Reconciliation of Non-GAAP Financial Measures” section contained within this Item 2 for definitions and reconciliations to the most comparable measures under U.S. GAAP.

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Overview

Peabody is a leading producer of metallurgical and thermal coal. In 2023, the Company produced and sold 126.7 million and 126.2 million tons of coal, respectively, from continuing operations. At June 30, 2024, the Company owned interests in 17 active coal mining operations located in the United States (U.S.) and Australia. Included in that count is Peabody’s 50% equity interest in Middlemount Coal Pty Ltd (Middlemount), which owns the Middlemount Mine in Queensland, Australia. In addition to its mining operations, the Company markets and brokers coal from other coal producers; trades coal and freight-related contracts; and since 2022, is partnered in a joint venture with the intent of developing various sites, including certain reclaimed mining land held by the Company in the U.S., for utility-scale photovoltaic solar generation and battery storage.

The Company reports its results of operations primarily through the following reportable segments: Seaborne Thermal, Seaborne Metallurgical, Powder River Basin, Other U.S. Thermal and Corporate and Other. Refer to Note 14. “Segment Information” to the accompanying unaudited condensed consolidated financial statements for further information regarding those segments and the components of its Corporate and Other segment.

Spot pricing for premium low-vol hard coking coal (Premium HCC), premium low-vol pulverized coal injection (Premium PCI) coal, Newcastle index thermal coal and API 5 index thermal coal, and prompt month pricing for PRB 8,880 Btu/Lb coal and Illinois Basin 11,500 Btu/Lb coal during the three months ended June 30, 2024 is set forth in the table below.

The seaborne pricing included in the table below is not necessarily indicative of the pricing the Company realized during the three months ended June 30, 2024 due to quality differentials and a portion of its seaborne sales being executed through annual and multi-year international coal supply agreements that contain provisions requiring both parties to renegotiate pricing periodically, with spot, index and quarterly sales arrangements also utilized. The Company’s typical practice is to negotiate pricing for seaborne metallurgical coal contracts on a quarterly, spot or index basis and seaborne thermal coal contracts on an annual, spot or index basis.

In the U.S., the pricing included in the table below is also not necessarily indicative of the pricing the Company realized during the three months ended June 30, 2024 since the Company generally sells coal under long-term contracts where pricing is determined based on various factors. Such long-term contracts in the U.S. may vary significantly in many respects, including price adjustment features, price reopener terms, coal quality requirements, quantity parameters, permitted sources of supply, treatment of environmental constraints, extension options, force majeure and termination and assignment provisions. Competition from alternative fuels such as natural gas and other fuel sources may also impact the Company’s realized pricing.


	High		Low		Average		June 30, 2024		August 2, 2024
Premium HCC (1)	$	256.50	$	223.50	$	242.31	$	234.00	$	215.00
Premium PCI coal (1)	186.00		142.00		163.36		182.00		186.50
Newcastle index thermal coal (1)	146.77		125.54		136.11		132.03		140.82
API 5 index thermal coal (1)	92.16		85.32		88.60		86.92		87.83
PRB 8,800 Btu/Lb coal (2)	13.70		13.40		13.52		13.70		13.90
Illinois Basin 11,500 Btu/Lb coal (2)	41.50		40.00		40.69		40.00		41.50

(1) Prices expressed per metric tonne.

(2) Prices expressed per short ton.

Within the global coal industry, supply and demand for its products and the supplies used for mining continue to be impacted by the ongoing Russian-Ukrainian conflict. As future developments related to the Russian-Ukrainian conflict and geopolitical instability in key energy producing regions are unknown, the global coal industry data for the six months ended June 30, 2024 presented herein may not be indicative of their ultimate impacts.

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Within the seaborne metallurgical coal market, coking coal prices have retreated from a high base during the six months ended June 30, 2024. Parts of the global steel market have reported tepid demand and thin profit margins during this period, restricting demand growth for metallurgical coal. In India, steel production was disrupted due to election activities and more recently the onset of the monsoon season; while in China, steel production was mixed with a weak property market slowing demand, partially offset by economic stimulus targeting the real estate sector. Australian high-quality coking coal showed signs of supply improvement during the six months ended June 30, 2024 which has weighed on coking coal prices, however periodic price support has been observed via various supply side disruptions, including rail and port maintenance curtailing exports in Queensland, the restriction of U.S. exports in Baltimore, Maryland and low domestic coal production in China. The June 2024 incident at the Grosvenor Mine in Queensland, Australia has further limited global exports. Despite these constraints, coking coal supply proved sufficient to meet demand during the period. In the PCI segment, prices were initially under pressure early in the year from reduced steel making productivity targets under thin margin conditions, but have since found support from shifting of trade flows from Russian to Australian supply amidst newly announced sanctions. In the coming period, seasonal restocking patterns and ongoing economic stimulus may lend support to metallurgical coal pricing. Overall, the market for metallurgical coal remains finely balanced and exposed to volatility, influenced by the rate of exports from Australia and economic performance in China, India and elsewhere.

Within the seaborne thermal coal market, global thermal coal prices were rangebound during the six months ended June 30, 2024, driven by healthy supply meeting elevated demand in Asian markets. In China, overall total generation demand has been elevated while domestic coal production has declined, which has driven stronger coal import demand year-over-year through the six months ended June 30, 2024. In India, strong growth in coal generation has supported increased import demand, despite elevated domestic coal production. Overall, global thermal coal markets remain turbulent amid ample supply and seasonal demand requirements in the Northern Hemisphere, as well as volatile global natural gas markets.

In the U.S., overall electricity demand increased approximately 5% year-over-year. Through the six months ended June 30, 2024, electricity generation from thermal coal has increased slightly year-over-year driven by higher overall electricity demand and despite low natural gas prices and stronger renewable generation. Coal’s share of electricity generation has declined to approximately 14% for the six months ended June 30, 2024, while wind and solar’s combined generation share is at 19% and the share of natural gas generation has decreased slightly to 40%. U.S. coal inventories have declined through June 30, 2024, resulting in stockpiles slightly below levels seen at the end of 2023. During the six months ended June 30, 2024, utility consumption of PRB coal was unchanged compared to the prior year period.

Centurion Mine

Peabody’s redevelopment of the Centurion Mine, an underground longwall metallurgical coal mine in Queensland, Australia, continues to advance as planned. The first development coal was mined in June 2024, and a second continuous mine was commissioned in July 2024. The first coal shipments from the Centurion Mine are expected in the fourth quarter of 2024, and the Company is targeting the commencement of longwall production in the first quarter of 2026. Approximately $200 million of the $489 million of capital expenditures to reach longwall production has been completed as of June 30, 2024. The benchmark premium hard coking coal from Centurion is expected to receive a premium price relative to other metallurgical coals.

Other

Wards Well Acquisition. The Company entered into a definitive agreement dated October 26, 2023, to acquire the southern part of the Wards Well tenements (Wards Well) which are adjacent to the Company’s Centurion Mine in Queensland, Australia. The acquisition was completed on April 16, 2024 for total consideration of $153.4 million, consisting of cash consideration of $134.4 million, cash transaction costs of $9.4 million and the non-cash settlement of existing receivables with the acquiree of $9.6 million.

Shoal Creek Insurance Recovery. On March 29, 2023, the Company’s Shoal Creek Mine experienced a fire involving void fill material utilized to stabilize the roof structure of the mine. On June 20, 2023, the Company announced that the Shoal Creek Mine, in coordination with the Mine Safety and Health Administration, had safely completed localized sealing of the affected area of the mine.

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Results of Operations

Three and Six Months Ended June 30, 2024 Compared to the Three and Six Months Ended June 30, 2023

Summary

The increase in income from continuing operations, net of income taxes for the three months ended June 30, 2024 compared to the same period in the prior year ($6.7 million) was driven by the current year insurance recovery related to the 2023 event at the Shoal Creek Mine ($109.5 million), lower operating costs and expenses ($58.1 million), and lower year-over-year provisions for taxes ($34.8 million) and the losses at the NARM and Shoal Creek Mines ($31.8 million). These favorable variances were offset by lower revenue ($226.8 million) due to no unrealized mark-to-market gains from derivative contracts related to forecasted sales in the current year, lower seaborne coal pricing and volume decreases in the U.S. thermal segments.

The decrease in income from continuing operations, net of income taxes for the six months ended June 30, 2024 compared to the same period in the prior year ($231.7 million) was driven by lower revenue ($607.2 million) due to no unrealized mark-to-market gains from derivative contracts related to forecasted sales in the current year, lower seaborne coal pricing and volume decreases in the U.S. thermal segments. This unfavorable variance was partially offset by a lower tax provision ($132.7 million), the current year insurance recovery related to the 2023 event at the Shoal Creek Mine ($109.5 million), lower operating costs and expenses ($90.5 million) and lower year-over-year provision for losses at the NARM and Shoal Creek Mines ($30.0 million).

Adjusted EBITDA for the three and six months ended June 30, 2024 reflected year-over-year decreases of $48.5 million and $278.6 million, respectively.

Tons Sold

The following table presents tons sold by operating segment:


	Three Months Ended June 30,		Increase (Decrease) to Volumes			Six Months Ended June 30,		Increase (Decrease) to Volumes
	2024	2023	Tons	%		2024	2023	Tons	%
	(Tons in millions)					(Tons in millions)
Seaborne Thermal	4.1	4.0	0.1	3	%	8.1	7.6	0.5	7	%
Seaborne Metallurgical	2.0	2.0	—	—	%	3.4	3.3	0.1	3	%
Powder River Basin	15.8	18.9	(3.1)	(16)	%	34.5	40.9	(6.4)	(16)	%
Other U.S. Thermal	3.7	3.8	(0.1)	(3)	%	6.9	8.3	(1.4)	(17)	%
Total tons sold from operating segments	25.6	28.7	(3.1)	(11)	%	52.9	60.1	(7.2)	(12)	%
Corporate and Other	—	0.2	(0.2)	(100)	%	0.1	0.3	(0.2)	(67)	%
Total tons sold	25.6	28.9	(3.3)	(11)	%	53.0	60.4	(7.4)	(12)	%

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Supplemental Financial Data

The following table presents supplemental financial data by operating segment:


	Three Months Ended June 30,				(Decrease) Increase				Six Months Ended June 30,				(Decrease) Increase
	2024		2023		$		%		2024		2023		$		%
Revenue per Ton (1)
Seaborne Thermal	$	74.43	$	100.59	$	(26.16)	(26)	%	$	72.86	$	98.81	$	(25.95)	(26)	%
Seaborne Metallurgical	149.29		190.13		(40.84)		(21)	%	159.10		202.33		(43.23)		(21)	%
Powder River Basin	14.02		13.71		0.31		2	%	13.80		13.80		—		—	%
Other U.S. Thermal	55.21		53.63		1.58		3	%	57.33		54.23		3.10		6	%
Costs per Ton (1)(2)
Seaborne Thermal	$	49.14	$	50.88	$	(1.74)	(3)	%	$	48.44	$	50.94	$	(2.50)	(5)	%
Seaborne Metallurgical	117.47		137.78		(20.31)		(15)	%	126.46		143.14		(16.68)		(12)	%
Powder River Basin	12.89		12.33		0.56		5	%	12.81		12.28		0.53		4	%
Other U.S. Thermal	45.53		39.71		5.82		15	%	45.40		40.22		5.18		13	%
Adjusted EBITDA Margin per Ton (1)(2)
Seaborne Thermal	$	25.29	$	49.71	$	(24.42)	(49)	%	$	24.42	$	47.87	$	(23.45)	(49)	%
Seaborne Metallurgical	31.82		52.35		(20.53)		(39)	%	32.64		59.19		(26.55)		(45)	%
Powder River Basin	1.13		1.38		(0.25)		(18)	%	0.99		1.52		(0.53)		(35)	%
Other U.S. Thermal	9.68		13.92		(4.24)		(30)	%	11.93		14.01		(2.08)		(15)	%

(1)This is an operating/statistical measure not recognized in accordance with U.S. GAAP. Refer to the “Reconciliation of Non-GAAP Financial Measures” section below for definitions and reconciliations to the most comparable measures under U.S. GAAP.

(2)Includes revenue-based production taxes and royalties; excludes depreciation, depletion and amortization; asset retirement obligation expenses; selling and administrative expenses; restructuring charges; asset impairment; amortization of take-or-pay contract-based intangibles; insurance recoveries; and certain other costs related to post-mining activities.

Revenue

The following table presents revenue by reporting segment:


	Three Months Ended June 30,				(Decrease) Increase to Revenue				Six Months Ended June 30,				Decrease to Revenue
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	307.5	$	399.5	$	(92.0)	(23)	%	$	591.4	$	746.0	$	(154.6)	(21)	%
Seaborne Metallurgical	294.3		372.5		(78.2)		(21)	%	541.3		660.9		(119.6)		(18)	%
Powder River Basin	221.9		259.7		(37.8)		(15)	%	476.0		565.0		(89.0)		(16)	%
Other U.S. Thermal	202.0		199.9		2.1		1	%	393.6		449.3		(55.7)		(12)	%
Corporate and Other	16.3		37.2		(20.9)		(56)	%	23.3		211.6		(188.3)		(89)	%
Revenue	$	1,042.0	$	1,268.8	$	(226.8)	(18)	%	$	2,025.6	$	2,632.8	$	(607.2)	(23)	%

Seaborne Thermal. Segment revenue decreased during the three and six months ended June 30, 2024 compared to the same periods in the prior year due to unfavorable realized prices ($117.4 million and $217.8 million, respectively), partially offset by favorable export volumes ($25.4 million and $63.2 million, respectively).

Seaborne Metallurgical. Segment revenue decreased during the three months ended June 30, 2024 compared to the same period in the prior year due to unfavorable realized prices ($56.8 million) and mix variances ($21.4 million). Segment revenue decreased during the six months ended June 30, 2024 compared to the same period in the prior year due to unfavorable realized prices ($181.1 million), offset by favorable volume and mix variances ($61.5 million) driven by increased production at the Shoal Creek Mine.

Powder River Basin. Segment revenue decreased during the three and six months ended June 30, 2024 compared to the same periods in the prior year due to unfavorable volumes ($38.2 million and $85.7 million, respectively) resulting from decreased demand driven by low natural gas pricing and mild weather.

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Other U.S. Thermal. Segment revenue increased during the three months ended June 30, 2024 compared to the same period in the prior year due to favorable realized prices ($3.2 million). Segment revenue decreased during the six months ended June 30, 2024 compared to the same period in the prior year due to unfavorable volumes ($69.4 million) resulting from decreased demand driven by low natural gas pricing and mild weather, partially offset by increased sales contract cancellation settlements ($13.1 million).

Corporate and Other. Segment revenue decreased during the three months ended June 30, 2024 compared to the same period in the prior year due to no unrealized mark-to-market gains from derivative contracts related to forecasted sales in the current year ($40.3 million) as all derivative contracts settled in 2023; offset by favorable results from trading activities ($19.0 million). Segment revenue decreased during the six months ended June 30, 2024 compared to the same period in the prior year due to no unrealized mark-to-market gains from derivative contracts related to forecasted sales in the current year ($159.0 million); prior year revenue related to the Company’s assignment of rights to its excess port and rail capacity ($19.2 million) as discussed in Note 15. “Other Events” to the accompanying unaudited condensed consolidated financial statements; and lower results from trading activities ($12.8 million).

Adjusted EBITDA

The following table presents Adjusted EBITDA for each of the Company’s reporting segments:


	Three Months Ended June 30,				(Decrease) Increase to Segment Adjusted EBITDA				Six Months Ended June 30,				Decrease to Segment Adjusted EBITDA
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	104.4	$	197.5	$	(93.1)	(47)	%	$	198.2	$	361.5	$	(163.3)	(45)	%
Seaborne Metallurgical	143.6		102.5		41.1		40	%	191.9		193.3		(1.4)		(1)	%
Powder River Basin	17.8		26.2		(8.4)		(32)	%	34.2		62.0		(27.8)		(45)	%
Other U.S. Thermal	35.4		51.9		(16.5)		(32)	%	81.9		116.1		(34.2)		(29)	%
Corporate and Other	8.5		(19.9)		28.4		143	%	(36.0)		15.9		(51.9)		(326)	%
Adjusted EBITDA (1)	$	309.7	$	358.2	$	(48.5)	(14)	%	$	470.2	$	748.8	$	(278.6)	(37)	%

(1)This is a financial measure not recognized in accordance with U.S. GAAP. Refer to the “Reconciliation of Non-GAAP Financial Measures” section below for definitions and reconciliations to the most comparable measures under U.S. GAAP.

Seaborne Thermal. Segment Adjusted EBITDA decreased during the three and six months ended June 30, 2024 compared to the same periods in the prior year as a result of lower realized prices net of sales price sensitive costs ($106.0 million and $200.8 million, respectively), partially offset by favorable volume and mix variances ($15.4 million and $39.2 million, respectively).

Seaborne Metallurgical. Segment Adjusted EBITDA increased during the three months ended June 30, 2024 compared to the same period in the prior year due to the Shoal Creek insurance recovery ($80.8 million) further discussed in Note 15. “Other Events” in the accompanying unaudited condensed consolidated financial statements and favorable mix variances ($15.4 million) driven by increased production from the Shoal Creek Mine following the fire in the first quarter of 2023, despite the lock outages during 2024. These increases were offset by lower realized prices net of sales price sensitive costs ($41.3 million) and unfavorable operational costs ($24.3 million).

Segment Adjusted EBITDA decreased during the six months ended June 30, 2024 compared to the same period in the prior year due to lower realized prices net of sales price sensitive costs ($151.0 million) and unfavorable operational costs ($47.7 million). These decreases were offset by favorable volumes ($88.4 million) driven by increased production from the Shoal Creek Mine following the fire in the first quarter of 2023, despite the lock outages during 2024; and the Shoal Creek insurance recovery ($80.8 million).

Powder River Basin. Segment Adjusted EBITDA decreased during the three and six months ended June 30, 2024 compared to the same periods in the prior year due to unfavorable volumes ($14.1 million and $44.9 million, respectively) and increased lease spend ($3.4 million and $5.4 million, respectively), offset by lower costs for materials, services, repairs and labor ($9.7 million and $22.3 million, respectively) and favorable commodity pricing ($1.4 million and $8.2 million, respectively).

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Other U.S. Thermal. Segment Adjusted EBITDA decreased during the three and six months ended June 30, 2024 compared to the same periods in the prior year due to unfavorable volumes ($22.3 million and $59.7 million, respectively), offset by favorable mine sequencing ($2.4 million and $11.5 million, respectively) and increased sales contract cancellation settlements (six months, $13.1 million).

Corporate and Other Adjusted EBITDA. The following table presents a summary of the components of Corporate and Other Adjusted EBITDA:


	Three Months Ended June 30,				(Decrease) Increase to Adjusted EBITDA				Six Months Ended June 30,				(Decrease) Increase to Adjusted EBITDA
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Middlemount (1)	$	1.9	$	3.7	$	(1.8)	(49)	%	$	1.1	$	6.0	$	(4.9)	(82)	%
Resource management activities (2)	9.9		6.0		3.9		65	%	14.3		8.3		6.0		72	%
Selling and administrative expenses	(22.1)		(21.7)		(0.4)		(2)	%	(44.1)		(44.5)		0.4		1	%
Other items, net (3)	18.8		(7.9)		26.7		338	%	(7.3)		46.1		(53.4)		(116)	%
Corporate and Other Adjusted EBITDA	$	8.5	$	(19.9)	$	28.4	143	%	$	(36.0)	$	15.9	$	(51.9)	(326)	%

(1)Middlemount’s results are before the impact of related changes in amortization of basis difference.

(2)Includes gains (losses) on certain surplus coal reserve, coal resource and surface land sales and property management costs and revenue.

(3)Includes trading and brokerage activities, costs associated with post-mining activities, gains (losses) on certain asset disposals, minimum charges on certain transportation-related contracts, costs associated with suspended operations including the Centurion Mine, the impact of foreign currency remeasurement and expenses related to the Company’s other commercial activities.

Corporate and Other Adjusted EBITDA increased during the three months ended June 30, 2024 compared to the same period in the prior year due to favorable trading results ($14.7 million) and the favorable net impact of foreign currency rate changes ($9.4 million).

Corporate and Other Adjusted EBITDA decreased during the six months ended June 30, 2024 compared to the same period in the prior year due to unfavorable trading results ($25.5 million); prior year revenue related to the Company’s assignment of rights to its excess port and rail capacity ($19.2 million) as discussed in Note 15. “Other Events” to the accompanying unaudited condensed consolidated financial statements; and the unfavorable net impact of foreign currency rate changes ($5.4 million).

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Income From Continuing Operations, Net of Income Taxes

The following table presents income from continuing operations, net of income taxes:


	Three Months Ended June 30,				(Decrease) Increase to Income				Six Months Ended June 30,				(Decrease) Increase to Income
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Adjusted EBITDA (1)	$	309.7	$	358.2	$	(48.5)	(14)	%	$	470.2	$	748.8	$	(278.6)	(37)	%
Depreciation, depletion and amortization	(82.9)		(80.6)		(2.3)		(3)	%	(162.7)		(156.9)		(5.8)		(4)	%
Asset retirement obligation expenses	(12.9)		(15.5)		2.6		17	%	(25.8)		(30.9)		5.1		17	%
Restructuring charges	(0.1)		(2.0)		1.9		95	%	(0.2)		(2.1)		1.9		90	%

Asset impairment	—		—		—		n.m.		—		(2.0)		2.0		100	%
Provision for NARM and Shoal Creek losses	(1.9)		(33.7)		31.8		94	%	(3.7)		(33.7)		30.0		89	%
Shoal Creek insurance recovery - property damage	28.7		—		28.7		n.m.		28.7		—		28.7		n.m.
Changes in amortization of basis difference related to equity affiliates	0.3		0.4		(0.1)		(25)	%	0.7		0.7		—		—	%
Interest expense, net of capitalized interest	(10.7)		(13.3)		2.6		20	%	(25.4)		(31.7)		6.3		20	%
Net loss on early debt extinguishment	—		(2.0)		2.0		100	%	—		(8.8)		8.8		100	%
Interest income	16.8		23.1		(6.3)		(27)	%	36.0		36.2		(0.2)		(1)	%

Unrealized gains on derivative contracts related to forecasted sales	—		40.3		(40.3)		(100)	%	—		159.0		(159.0)		(100)	%
Unrealized gains (losses) on foreign currency option contracts	2.4		2.8		(0.4)		(14)	%	(3.3)		0.6		(3.9)		(650)	%
Take-or-pay contract-based intangible recognition	0.8		0.6		0.2		33	%	1.5		1.2		0.3		25	%
Income tax provision	(39.4)		(74.2)		34.8		47	%	(59.5)		(192.2)		132.7		69	%
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	6.7	3	%	$	256.5	$	488.2	$	(231.7)	(47)	%

Depreciation, Depletion and Amortization. The following table presents a summary of depreciation, depletion and amortization expense by reporting segment:


	Three Months Ended June 30,				(Decrease) Increase to Income				Six Months Ended June 30,				(Decrease) Increase to Income
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	(28.7)	$	(27.6)	$	(1.1)	(4)	%	$	(56.3)	$	(51.4)	$	(4.9)	(10)	%
Seaborne Metallurgical	(22.9)		(22.9)		—		—	%	(44.7)		(44.0)		(0.7)		(2)	%
Powder River Basin	(12.8)		(10.6)		(2.2)		(21)	%	(25.3)		(22.3)		(3.0)		(13)	%
Other U.S. Thermal	(16.6)		(17.1)		0.5		3	%	(30.6)		(34.8)		4.2		12	%
Corporate and Other	(1.9)		(2.4)		0.5		21	%	(5.8)		(4.4)		(1.4)		(32)	%
Total	$	(82.9)	$	(80.6)	$	(2.3)	(3)	%	$	(162.7)	$	(156.9)	$	(5.8)	(4)	%

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Additionally, the following table presents a summary of the Company’s weighted-average depletion rate per ton for active mines in each of its operating segments:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Seaborne Thermal	$	2.08	$	2.09	$	2.09	$	2.13
Seaborne Metallurgical	2.47		1.82		2.60		1.96
Powder River Basin	0.35		0.30		0.36		0.30
Other U.S. Thermal	1.69		1.33		1.62		1.26

The increases in the weighted-average depletion rate per ton for both the Seaborne Metallurgical and the Other U.S. Thermal segments during the three and six months ended June 30, 2024 compared to the same periods in the prior year reflect the impact of volume and mix variances across the segments.

Provision for NARM and Shoal Creek Losses. The provision recorded during the prior year periods was for losses related to the events at the NARM and Shoal Creek Mines, as discussed in Note 15. “Other Events” in the accompanying unaudited condensed consolidated financial statements. Incremental repair costs related to the tornado damage at NARM were recorded during the current year.

Shoal Creek Insurance Recovery - Property Damage. During June 2024, the Company reached a settlement with its insurers and various re-insurers related to the Shoal Creek losses and recorded a $109.5 million insurance recovery, as discussed in Note 15. “Other Events” in the accompanying unaudited condensed consolidated financial statements. Of this amount, Adjusted EBITDA excludes an allocated amount applicable to total equipment losses recognized at the time of the insurance recovery, which consisted of $28.7 million recognized during the year ended December 31, 2023. The remaining $80.8 million, applicable to incremental costs and business interruption recoveries, is included in Adjusted EBITDA for the three and six months ended June 30, 2024.

Interest Expense, Net of Capitalized Interest. The decrease in expense during the three and six months ended June 30, 2024 compared to the same periods in the prior year was driven by lower interest and fees for financial assurance instruments and the capitalization of interest related to the redevelopment of the Centurion Mine.

Net Loss on Early Debt Extinguishment. The loss recognized during the prior year was primarily related to the Company’s terminated letter of credit facility as further discussed in Note 12. “Financial Instruments and Other Guarantees” to the accompanying unaudited condensed consolidated financial statements.

Interest Income. The decrease in interest income during the three months ended June 30, 2024 was primarily due to lower average cash balances, including restricted cash balances on which the Company earns interest, in the current year.

Unrealized Gains on Derivative Contracts Related to Forecasted Sales. The prior year unrealized gains primarily relate to mark-to-market activity on derivative contracts related to forecasted coal sales. As further described in Note 6. "Derivatives and Fair Value Measurements" to the Annual Report on Form 10-K for the year ended December 31, 2023, all derivative contracts related to forecasted coal sales settled in 2023.

Income Tax Provision. The decrease in the income tax provision during the three and six months ended June 30, 2024 compared to the same periods in the prior year was primarily due to lower pretax income. Refer to Note 8. “Income Taxes” to the accompanying unaudited condensed consolidated financial statements for additional information.

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Net Income Attributable to Common Stockholders

The following table presents net income attributable to common stockholders:


	Three Months Ended June 30,				Increase (Decrease) to Income				Six Months Ended June 30,				(Decrease) Increase to Income
	2024		2023		$		%		2024		2023		$		%
	(Dollars in millions)								(Dollars in millions)
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	6.7	3	%	$	256.5	$	488.2	$	(231.7)	(47)	%
Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(0.3)		(23)	%	(2.3)		(2.6)		0.3		12	%
Net income	209.2		202.8		6.4		3	%	254.2		485.6		(231.4)		(48)	%
Less: Net income attributable to noncontrolling interests	9.8		23.6		(13.8)		(58)	%	15.2		37.9		(22.7)		(60)	%
Net income attributable to common stockholders	$	199.4	$	179.2	$	20.2	11	%	$	239.0	$	447.7	$	(208.7)	(47)	%

Net Income Attributable to Noncontrolling Interests. The decrease in the results attributable to noncontrolling interests during the three and six months ended June 30, 2024 compared to the same periods in the prior year was primarily due to a decline in the financial results of Peabody’s majority-owned Wambo operations in which there is an outside non-controlling interest.

Diluted Earnings per Share (EPS)

The following table presents diluted EPS:


	Three Months Ended June 30,				Increase to EPS				Six Months Ended June 30,				Decrease to EPS
	2024		2023		$		%		2024		2023		$		%
Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.43	$	1.16	$	0.27	23	%	$	1.72	$	2.85	$	(1.13)	(40)	%
Loss from discontinued operations	(0.01)		(0.01)		—		—	%	(0.02)		(0.02)		—		—	%
Net income attributable to common stockholders	$	1.42	$	1.15	$	0.27	23	%	$	1.70	$	2.83	$	(1.13)	(40)	%

Diluted EPS is commensurate with the changes in results from continuing operations and discontinued operations during that period. Diluted EPS reflects weighted average diluted common shares outstanding of 142.8 million and 159.0 million for the three months ended June 30, 2024 and 2023, respectively, and 143.8 million and 160.2 million for the six months ended June 30, 2024 and 2023, respectively.

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Reconciliation of Non-GAAP Financial Measures

Adjusted EBITDA is defined as income from continuing operations before deducting net interest expense, income taxes, asset retirement obligation expenses and depreciation, depletion and amortization. Adjusted EBITDA is also adjusted for the discrete items that management excluded in analyzing each of its segment’s operating performance, as displayed in the reconciliations below.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Depreciation, depletion and amortization	82.9		80.6		162.7		156.9
Asset retirement obligation expenses	12.9		15.5		25.8		30.9
Restructuring charges	0.1		2.0		0.2		2.1

Asset impairment	—		—		—		2.0
Provision for NARM and Shoal Creek losses	1.9		33.7		3.7		33.7
Shoal Creek insurance recovery - property damage	(28.7)		—		(28.7)		—
Changes in amortization of basis difference related to equity affiliates	(0.3)		(0.4)		(0.7)		(0.7)
Interest expense, net of capitalized interest	10.7		13.3		25.4		31.7
Net loss on early debt extinguishment	—		2.0		—		8.8
Interest income	(16.8)		(23.1)		(36.0)		(36.2)

Unrealized gains on derivative contracts related to forecasted sales	—		(40.3)		—		(159.0)
Unrealized (gains) losses on foreign currency option contracts	(2.4)		(2.8)		3.3		(0.6)
Take-or-pay contract-based intangible recognition	(0.8)		(0.6)		(1.5)		(1.2)
Income tax provision	39.4		74.2		59.5		192.2
Total Adjusted EBITDA	$	309.7	$	358.2	$	470.2	$	748.8

Total Reporting Segment Costs is defined as operating costs and expenses adjusted for the discrete items that management excluded in analyzing each of its segments’ operating performance, as displayed in the reconciliations below.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Operating costs and expenses	$	803.9	$	862.0	$	1,618.1	$	1,708.6
Unrealized gains (losses) on foreign currency option contracts	2.4		2.8		(3.3)		0.6
Take-or-pay contract-based intangible recognition	0.8		0.6		1.5		1.2

Net periodic benefit credit, excluding service cost	(10.2)		(9.7)		(20.3)		(19.4)
Total Reporting Segment Costs	$	796.9	$	855.7	$	1,596.0	$	1,691.0

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The following table presents Total Reporting Segment Costs by reporting segment:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Seaborne Thermal	$	203.1	$	202.0	$	393.2	$	384.5
Seaborne Metallurgical	231.5		270.0		430.2		467.6
Powder River Basin	204.1		233.5		441.8		503.0
Other U.S. Thermal	166.6		148.0		311.7		333.2
Corporate and Other	(8.4)		2.2		19.1		2.7
Total Reporting Segment Costs	$	796.9	$	855.7	$	1,596.0	$	1,691.0

Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenue by segment and Adjusted EBITDA by segment (excluding insurance recoveries), respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton.

The following tables present tons sold, revenue, Total Reporting Segment Costs and Adjusted EBITDA by operating segment:


	Three Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	4.1		2.0		15.8		3.7

Revenue	$	307.5	$	294.3	$	221.9	$	202.0
Total Reporting Segment Costs	203.1		231.5		204.1		166.6
Adjusted EBITDA, excluding Shoal Creek insurance recovery	$	104.4	$	62.8	$	17.8	$	35.4
Shoal Creek insurance recovery - business interruption	—		80.8		—		—
Adjusted EBITDA	$	104.4	$	143.6	$	17.8	$	35.4

Revenue per Ton	$	74.43	$	149.29	$	14.02	$	55.21
Costs per Ton	49.14		117.47		12.89		45.53
Adjusted EBITDA Margin per Ton	$	25.29	$	31.82	$	1.13	$	9.68


	Three Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	4.0		2.0		18.9		3.8

Revenue	$	399.5	$	372.5	$	259.7	$	199.9
Total Reporting Segment Costs	202.0		270.0		233.5		148.0
Adjusted EBITDA	$	197.5	$	102.5	$	26.2	$	51.9

Revenue per Ton	$	100.59	$	190.13	$	13.71	$	53.63
Costs per Ton	50.88		137.78		12.33		39.71
Adjusted EBITDA Margin per Ton	$	49.71	$	52.35	$	1.38	$	13.92

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	Six Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	8.1		3.4		34.5		6.9

Revenue	$	591.4	$	541.3	$	476.0	$	393.6
Total Reporting Segment Costs	393.2		430.2		441.8		311.7
Adjusted EBITDA, excluding Shoal Creek insurance recovery	$	198.2	$	111.1	$	34.2	$	81.9
Shoal Creek insurance recovery - business interruption	—		80.8		—		—
Adjusted EBITDA	$	198.2	$	191.9	$	34.2	$	81.9

Revenue per Ton	$	72.86	$	159.10	$	13.80	$	57.33
Costs per Ton	48.44		126.46		12.81		45.40
Adjusted EBITDA Margin per Ton	$	24.42	$	32.64	$	0.99	$	11.93


	Six Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	7.6		3.3		40.9		8.3

Revenue	$	746.0	$	660.9	$	565.0	$	449.3
Total Reporting Segment Costs	384.5		467.6		503.0		333.2
Adjusted EBITDA	$	361.5	$	193.3	$	62.0	$	116.1

Revenue per Ton	$	98.81	$	202.33	$	13.80	$	54.23
Costs per Ton	50.94		143.14		12.28		40.22
Adjusted EBITDA Margin per Ton	$	47.87	$	59.19	$	1.52	$	14.01

Available Free Cash Flow is defined as operating cash flow less investing cash flow and distributions to noncontrolling interests; plus/minus changes to restricted cash and collateral and other anticipated expenditures. See the table below for a reconciliation of Available Free Cash Flow to its most comparable measure under U.S. GAAP.


	Six Months Ended June 30, 2024
	(Dollars in millions)
Net cash provided by operating activities	$	126.8
- Net cash used in investing activities	(316.8)
- Distributions to noncontrolling interests	(18.5)
+/- Changes to restricted cash and collateral	(17.1)
- Anticipated expenditures or other requirements	—
Available Free Cash Flow	$	(225.6)

Regulatory Update

Other than as described in the following section, there were no significant changes to the Company’s regulatory or global climate matters subsequent to December 31, 2023. This section should be considered in connection with the Company’s regulatory and global climate matters as outlined in Part I, Item 1. “Business” in its Annual Report on Form 10-K for the year ended December 31, 2023.

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Regulatory Matters - U.S.

National Ambient Air Quality Standards (NAAQS). The Clean Air Act (CAA) requires the U.S. Environmental Protection Agency (EPA) to review national ambient air quality standards every five years to determine whether revisions to current standards are appropriate. On March 6, 2024, the EPA revised the level of the primary standard for fine particulate matter (PM 2.5), lowering the annual standard from 12.0 ug/m3 to 9.0 ug/m3. States are now required to take several actions to implement the standards which could require fossil fuel electric generating units (EGUs) and non-EGUs to install additional emission control technologies or operate in a different manner. Such actions could potentially increase the cost of utilizing fossil fuels for electric generation and industrial uses.

The EPA is also in the process of reviewing the current ozone NAAQS. The level of the ozone NAAQS can also affect requirements to install new or improved emission control technologies at fossil fuel-fired EGUs and non-EGU industrial sources.

Final New Source Performance Standards (NSPS) for Fossil Fuel-Fired EGUs. The EPA promulgated a final rule to limit carbon dioxide (CO2) from new, modified and reconstructed fossil fuel-fired EGUs under Section 111(b) of the CAA on August 3, 2015, and published it in the Federal Register on October 23, 2015.

The rule requires that newly-constructed fossil fuel-fired steam generating units achieve an emission standard for CO2 (known as the Best System of Emission Reduction (BSER)) which is based on the performance of a supercritical pulverized coal boiler implementing partial carbon capture, utilization and storage (CCUS). Modified and reconstructed fossil fuel-fired steam generating units must implement the most efficient generation achievable through a combination of best operating practices and equipment upgrades, to meet an emission standard consistent with best historical performance. Reconstructed EGUs must implement the most efficient generating technology based on the size of the unit.

Numerous legal challenges to the final rule were filed in the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit). Sixteen separate petitions for review were filed, and the challengers include 25 states, utilities, mining companies (including Peabody), labor unions, trade organizations and other groups. The cases were consolidated under the case filed by North Dakota (D.C. Cir. No. 15-1381). Four additional cases were filed seeking review of the EPA’s denial of reconsideration petitions in a final action published in the May 6, 2016 Federal Register entitled “Reconsideration of Standards of Performance for Greenhouse Gas Emissions From New, Modified, and Reconstructed Stationary Sources: Electric Generating Units; Notice of final action denying petitions for reconsideration.” Pursuant to an order of the court, these cases remain in abeyance, subject to requirements for the EPA to file 90-day status reports.

On December 20, 2018, the EPA proposed to revise the 2015 NSPS to modify the minimum requirements for newly constructed coal-fired units from partial CCUS to efficiency-based standards. (83 Fed. Reg. 65,424 (Dec. 20, 2018)). In contrast to the 2015 rule, the proposed rule defined BSER as the most efficient demonstrated steam cycle in combination with the best operating practices. The EPA indicated that the primary reason for revising BSER was the high cost and limited geographic availability of CCUS technology. On May 23, 2023, however, the EPA published a notice of proposed rulemaking addressing NSPS from new, modified and reconstructed fossil-fuel steam EGUs. In contrast to the 2018 proposed rule, the 2023 proposed rule did not propose to amend the 2015 NSPS for coal-fired EGUs. Status reports filed with the D.C. Circuit in North Dakota v. EPA indicate that litigation on the 2015 rule should remain in abeyance pending the EPA’s action on the 2018 proposed rule and the 2023 proposed rule. As indicated in the following section, on May 9, 2024, the EPA published the final rule in the Federal Register based on the 2023 proposed rule. This final rule did not amend the 2015 NSPS for coal-fired EGUs, but indicated that the EPA will continue to consider whether or not to make revisions to that rule in the future.

EPA Regulation of Greenhouse Gas Emissions from New and Existing Fossil Fuel-Fired EGUs. On May 9, 2024, the EPA published a final rule for new, modified and reconstructed fossil fuel-fired EGUs in the Federal Register. The final rule consists of four elements: (1) revised NSPS for controlling CO2 emissions from new and reconstructed stationary combustion turbines; (2) revised NSPS for fossil fuel-fired steam EGUs that undertake a large modification; (3) emission guidelines for existing fossil fuel-fired steam EGUs; and (4) repeal of the Affordable Clean Energy rule promulgated in 2019.

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With respect to existing fossil fuel-fired steam EGUs (primarily coal-fired) the EPA determined that the BSER that is adequately demonstrated is carbon capture and sequestration (CCS) with 90% capture of CO2 emissions. Pursuant to the final rule, existing fossil fuel-fired steam EGUs that intend to operate in the long-term will be required to comply with a CO2 emission rate based on CCS with 90% capture by January 1, 2032. Existing fossil fuel-fired steam EGUs that will permanently cease operations by January 1, 2039 are not subject to emission standards based on 90% CO2 capture, but will need to meet an emission rate based on co-firing with 40% natural gas by January 1, 2030. (This translates into a 16% reduction in CO2 emissions determined from a unit-specific baseline). Existing fossil fuel-fired steam EGUs that permanently cease operations by January 1, 2032 are exempt from these requirements.

All requirements related to existing affected units in the final rule – whether fired by coal or natural gas – will be imposed through state plans that are permitted to take into account the remaining useful life of a generating unit when determining appropriate controls. Under the final rule, such plans must provide for the implementation and enforcement of the NSPS, but states may apply less stringent standards of performance in certain conditions, as specified in EPA regulations. States are also permitted to impose more stringent standards. In addition, the final rule includes several “reliability” mechanisms to allow states to provide alternative emission limitations or compliance date extensions in order to maintain adequate electric generation resources and grid reliability.

Finally, as part of the final rule, any newly constructed stationary combustion turbine (SCT), where construction or reconstruction of the unit was commenced after May 23, 2023, will be subject to CO2 emission limits based on whether it is considered to be a low load, intermediate load or base load EGU. In addition, for affected base load SCTs, a second phase emission standard applies based on 90% CCS as of January 1, 2032. Any new fossil-fuel steam EGU (where construction or reconstruction was commenced after June 18, 2014) will need to comply with standards promulgated in 2015.

The final rule is subject to numerous legal challenges that have been consolidated in the U.S. Court of Appeals for the Eighth Circuit (Eighth Circuit). If the Eighth Circuit affirms the final rule, as implemented by the EPA and states, it could have a substantial impact on the use of coal and natural gas for the generation of electricity.

Effluent Limitations Guidelines for the Steam Electric Power Generating Industry. In 2015, the EPA published a final rule setting requirements for wastewater discharge from EGUs. In 2020, the EPA finalized revisions to certain requirements in the 2015 rule. On May 9, 2024, the EPA published a final rule that would establish more stringent standards for flue gas desulfurization wastewater, bottom ash transport water, combustion residual leachate and legacy wastewater discharged from certain surface impoundments. The final revised effluent limitations guidelines would significantly increase costs for many coal-fueled steam electric power plants. In addition, the recently finalized final rule allows EGUs that commit to ceasing coal combustion by December 31, 2034, to comply with less stringent wastewater discharge requirements during the interim. The final rule is subject to numerous legal challenges that have been consolidated in the Eighth Circuit. If the Eighth Circuit affirms the final rule, it could influence fuel switching or additional coal generating unit retirements by the end of 2034.

Rules for Disposal of Coal Combustion Residuals (CCR) from Electric Utilities; Federal CCR Permit Program and Revisions to Closure Requirements. On February 20, 2020, as required by the Water Infrastructure Improvements for the Nation Act, the EPA proposed a federal permitting program for the disposal of CCR in surface impoundments and landfills. Under the proposal, the EPA would directly implement the permit program in Indian Country and at CCR units located in states that have not submitted their own CCR permit program for approval. The proposal includes requirements for federal CCR permit applications, content and modification, as well as procedural requirements. The comment period for the EPA’s proposal ended on April 20, 2020. Although the EPA had planned to finalize this rule in 2021, the EPA now expects to issue a final rule around October 2024. Separately, on August 28, 2020 and November 12, 2020, the EPA finalized two sets of amendments to its 2015 CCR rule to partially address the D.C. Circuit’s 2018 decision holding that certain provisions of that rule were not sufficiently protective. On May 8, 2024, the EPA published a final rule containing additional amendments to the 2015 CCR rule that further address aspects of the D.C. Circuit’s 2018 decision. Finally, the EPA is still considering whether to finalize additional revisions to the 2015 CCR Rule related to closure of CCR units.

Cross State Air Pollution Rule (CSAPR) and CSAPR Update Rule. The CSAPR and related updates require numerous U.S. states and the District of Columbia to reduce power plant emissions that cross state lines and significantly contribute to ozone and/or fine PM pollution in other states.

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On March 15, 2023, the EPA issued a final rule to address regional ozone transport by imposing new federal ozone season emission budgets for nitrogen oxide (NOx) in 23 states, including California, Nevada, Oklahoma and Texas, as well as some Indian reservations. The rule includes state emission budgets for NOx affecting fossil fuel-fired power plants and a “backstop daily emissions rate” for large coal-fired power plants if they exceed specified limits. The rule also sets first-time limits on certain industrial sources that will apply starting with the 2026 ozone season in 20 states. The EPA estimates that annual compliance costs (for 2023 through 2042) will be $770 million to $910 million. These emission limitations would apply in addition to requirements contained in state implementation plans to control ozone precursors in affected states, although states have the option to replace these limits with equally strict or more stringent limitations. When implemented, this rule could influence the closure of some coal generating units that have not installed selective catalytic reduction technologies.

Implementation of the rule for existing sources (accomplished through state implementation plans) was challenged in several U.S. Courts of Appeal, resulting in different court opinions and in requirements being implemented in some states, but stayed in others. On June 27, 2024, the U.S. Supreme Court issued a stay of the rule in 11 states pending the disposition of a petition for review of the rule in the D.C. Circuit and any subsequent timely petition for certiorari filed with and granted by the U.S. Supreme Court.

Regional Haze. The CAA contains a national visibility goal for the “prevention of any future, and the remedying of any existing, impairment of visibility in Class I areas which impairment results from man-made air pollution.” The EPA promulgated comprehensive regulations in 1999 requiring all states to submit plans to address regional haze that could affect 156 national parks and wilderness areas, including requirements for certain sources to install the best available retrofit technology and for states to demonstrate “reasonable progress” towards meeting the national visibility goal. States are required to revise plans every 10 years. On March 29, 2024, the EPA published a proposed consent decree under which deadlines would be established for the EPA to take final action to approve, disapprove or conditionally approve, in whole or in part, state regional haze implementation plans for 34 states (at various dates from June 28, 2024 to December 31, 2026). The EPA subsequently filed a motion to approve the consent judgement in the U.S. District Court for the District of Columbia which remains pending.

Federal Coal Leasing Moratorium. The Executive Order on Promoting Energy Independence and Economic Growth (EI Order), signed on March 28, 2017, lifted the Department of Interior’s federal coal leasing moratorium and rescinded guidance on the inclusion of social cost of carbon in federal rulemaking. Following the EI Order, the Interior Secretary issued Order 3349 ending the federal coal leasing moratorium. Environmental groups took the issue to court (District of Montana) and in April 2019, the court held the lifting of the moratorium triggered National Environmental Policy Act (NEPA) review. On May 22, 2020, the court held that the Department of Interior’s issuance of an Environmental Assessment and Finding of No Significant Impact (FONSI) remedied the prior NEPA violations. Thereafter, environmental groups amended their complaint to challenge the Environmental Assessment and FONSI. On August 12, 2022, the court invalidated the Environmental Assessment and FONSI and reinstated the moratorium until completion of a sufficient NEPA analysis. On appeal, the U.S. Court of Appeals for the Ninth Circuit (Ninth Circuit) reversed the district court on February 21, 2024, explaining that the lawsuit was mooted by the Department of Interior’s April 2021 order revoking Order 3349. The Ninth Circuit directed the district court to dismiss the case as moot.

Endangered Species Act (ESA). The ESA of 1973 and counterpart state legislation is intended to protect species whose populations allow for categorization as either endangered or threatened. Changes in listings or requirements under these regulations could have a material adverse effect on Peabody’s costs or its ability to mine some of its properties in accordance with its current mining plans. During the Trump Administration, the Departments of Interior and Commerce finalized five rules aiming to streamline and update the ESA. But in June 2021, the agencies announced their plan to revise, rescind or reinstate the rules that were finalized (or withdrawn) during the Trump Administration that conflict with the Biden Administration’s objectives. The agencies issued proposed rules on June 22, 2023, and they published three final revised rules on April 5, 2024.

SEC Climate-Related Disclosures. On March 6, 2024, the SEC adopted final rules it expects will enhance and standardize climate-related disclosures by public companies and in public offerings. Specifically, the final rules will require disclosure of, among other things, climate-related risks that have had or are reasonably likely to have a material impact on a public company’s business strategy, results of operations or financial condition; certain greenhouse gas (GHG) emissions associated with a public company along with, in many cases, an attestation report by a GHG emissions attestation provider; and certain climate-related financial metrics to be included in a company’s audited financial statements. The final rules were challenged by multiple parties, and the cases were consolidated into a judicial review by the Eighth Circuit. On April 4, 2024, the SEC voluntarily stayed implementation of the final rules pending such judicial review. The Company is assessing the potential impact of the final rules.

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Regulatory Matters - Australia

National Greenhouse and Energy Reporting Act 2007 (NGER Act). The NGER Act imposes requirements for corporations meeting a certain threshold to register and report greenhouse gas emissions and abatement actions, as well as energy production and consumption as part of a single, national reporting system. The Clean Energy Regulator administers the NGER Act. The federal Department of Environment and Energy is responsible for NGER Act-related policy developments and review. In May 2023, the Australian Parliament passed reforms to the National Greenhouse and Energy Reporting (Safeguard Mechanism) Rule 2015. The reforms commenced on July 1, 2023 and introduced site specific baseline emissions for heavy emitting facilities as benchmarks for year-on-year improvement (proposed to be 4.9% each year to 2030) before transitioning to industry average emissions benchmarks by 2030. Proponents will earn tradeable credits (Safeguard Mechanism Credits) when emissions are below their baselines or can purchase credits to offset emissions. Access to existing Australian Carbon Credit Units will continue unchanged albeit with a price ceiling of $75 Australian dollars per tonne of CO2 in 2023-24, increasing with the Consumer Price Index plus 2% each year. In June 2024 amendments to the NGER Act came into effect requiring open-cut mines covered by the Safeguard Mechanism that currently report fugitive methane emissions using a basic method with minimal data inputs (Method 1) to transition over a two-year period to a more complex method requiring site-level sampling and analysis (Methods 2 or 3). This change in reporting methods is expected to increase the Safeguard Mechanism liability position of open-cut mining operations in Queensland. The impacts of this change are currently being assessed.

New South Wales (NSW) Environmental. Under the NSW Environmental Planning and Assessment Act 1979 (EPA Act), environmental planning instruments must be considered when approving a mining project development application. Decision makers review the significance of a resource and the state and regional economic benefits of a proposed coal mine when considering a development application on the basis that it is an element of the “public interest” consideration contained in the relevant legislation. Effective from March 1, 2018, the EPA Act was amended to introduce a number of changes to planning laws in New South Wales. The EPA Act was further amended in June 2018 to revoke a process for modifying development approvals under the former Section 75W of the EPA Act. As a result, new development approvals will need to be obtained unless the proposed project will be substantially the same development as it was when the development approval was last modified under Section 75W, in which case the existing development approval can be modified. If a new development approval is required then this could take additional time to achieve.

On April 3, 2024, the Environment Protection Legislation Amendment (Stronger Regulation and Penalties) Bill 2024 was assented to by the Parliament of New South Wales. The bill increases the NSW Environment Protection Agency’s (NSW EPA) powers across a range of environmental legislation including increasing the NSW EPA’s maximum penalties for serious environmental offenses; increasing the NSW EPA’s on-the-spot maximum fines; providing the NSW EPA the power to issue what will be known as ‘Preliminary Investigation Notices’ which permit the NSW EPA to force a person to help the NSW EPA compile a criminal case against the person or against another person; extending the monetary benefits order so that it can apply to any ‘related entity’ as defined in the Corporations Act 2001; providing the NSW EPA the power to issue what will be known as ‘Recall Notices’ which order responsible entities to recall contaminated substances suspected of causing harm to the community and environment; and providing the NSW EPA the power to issue what will be known as ‘name and shame’ public warnings to call out poor and repeat environmental performers for the protection of communities. The reform also creates a new power in Australia for the NSW Land and Environment Court that empowers the court to ban offenders, upon the NSW EPA’s application, with a poor compliance history from seeking and obtaining environmental protection licenses.

On August 25, 2017, the Biodiversity Conservation Act 2016 (BC Act) commenced in NSW and imposes a revised framework for the assessment of potential impacts on biodiversity that may be caused by a development, such as a proposed mining project. The BC Act requires these potential impacts on biodiversity to be offset in perpetuity, by one or more of the following means: securing land based offsets and retiring biodiversity credits, making a payment into a biodiversity conservation fund or in some cases through mine site ecological rehabilitation. The data collected from the biodiversity impact assessment process is inputted into a new offsets payment calculator in order to determine the amount payable by the proponent to offset the impacts. The proposed development can only proceed once the biodiversity offset obligations have been satisfied. On July 18, 2024, following an independent review of the BC Act, the NSW government announced it would amend the BC Act to reform the biodiversity offsets scheme by introducing a new statutory standard requiring mining proponents to demonstrate how they have genuinely avoided and minimized impacts to biodiversity and removing the option for major mining proponents to meet a credit obligation through a commitment to ecological mine site rehabilitation. When enacted, these and other proposed changes have the potential to affect approval processes for future NSW mining projects.

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New South Wales Coal Directions. The State of New South Wales enacted the Energy and Utilities Administration Amendment Act 2022 granting the State Premier and Minister for Energy the ability to issue directions in the event of a coal market price emergency (among other powers). On December 22, 2022, the State Premier declared such an emergency, intended to control coal and electricity pricing. Subsequently, directions were issued to Peabody Energy Australia Pty Ltd and other coal producers with operations in NSW, which were amended at various dates. The most recent directions required Peabody Energy Australia Pty Ltd to reserve a portion of coal produced by Wambo Coal Pty Ltd and Wilpinjong Coal Pty Ltd for sale to NSW power generators at a capped price until June 30, 2024 and imposed additional reporting obligations to demonstrate compliance. The Australian Energy Regulator has confirmed that the directions have ended, and the last report was submitted on July 12, 2024.

Risks Related to Global Climate Change

There have been no significant changes to the Company’s global climate matters subsequent to December 31, 2023. Refer to Part I, Item 1. “Business” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023 for information regarding the Company’s global climate matters.

Liquidity and Capital Resources

Overview

The Company’s primary source of cash is proceeds from the sale of its coal production to customers. The Company has also generated cash from the sale of non-strategic assets, including coal reserves, coal resources and surface lands, and, from time to time, borrowings under its credit facilities and the issuance of securities. The Company’s primary uses of cash include the cash costs of coal production, capital expenditures, coal reserve lease and royalty payments, debt service costs, finance and operating lease payments, postretirement plans, take-or-pay obligations, post-mining reclamation obligations, collateral and margining requirements, dividends, share repurchases and selling and administrative expenses. The Company has also used cash for early debt retirements.

Any future determinations to return capital to stockholders, such as dividends or share repurchases, will depend on a variety of factors, including the Company’s net income or other sources of cash, liquidity position and potential alternative uses of cash, such as internal development projects or acquisitions, as well as economic conditions and expected future financial results. The Company’s ability to early retire debt, declare dividends or repurchase shares in the future will depend on its future financial performance, which in turn depends on the successful implementation of its strategy and on financial, competitive, regulatory, technical and other factors, general economic conditions, demand for and selling prices of coal and other factors specific to its industry, many of which are beyond the Company’s control.

Liquidity

As of June 30, 2024, the Company’s cash and cash equivalents balances totaled $621.7 million, including approximately $388 million held by U.S. subsidiaries, approximately $217 million held by Australian subsidiaries and the remainder held by other foreign subsidiaries in accounts predominantly domiciled in the U.S. A significant majority of the cash held by the Company’s foreign subsidiaries is denominated in U.S. dollars. This cash is generally used to support non-U.S. liquidity needs, including capital and operating expenditures in Australia and payment of the foreign subsidiaries’ share of certain U.S. corporate expenditures. From time to time, the Company may repatriate profits from its foreign subsidiaries to the U.S. in the form of intercompany dividends. During the six months ended June 30, 2024, no profits from foreign subsidiaries were repatriated. If foreign-held cash is repatriated in the future, the Company does not expect restrictions or potential taxes will have a material effect to its near-term liquidity.

The Company’s available liquidity decreased from $1,059.7 million as of December 31, 2023 to $940.8 million as of June 30, 2024. Available liquidity was comprised of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Cash and cash equivalents	$	621.7	$	969.3
Revolving credit facility availability	222.0		—
Accounts receivable securitization program availability	97.1		90.4
Total liquidity	$	940.8	$	1,059.7

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Capital Returns to Shareholders

The Company repurchased approximately 3.2 million shares of its common stock for $80.5 million, including commission fees, and paid dividends of $19.1 million during the six months ended June 30, 2024.

Surety Agreement Amendment and Collateral Requirements

In April 2023, the Company amended its existing agreement with the providers of its surety bond portfolio, dated November 6, 2020. Under the April 2023 amendment, the Company and its surety providers agreed to a maximum aggregate collateral amount of $721.8 million based upon bonding levels at the effective date of the amendment. This maximum collateral amount will vary prospectively as bonding levels increase or decrease. The amendment extended the agreement through December 31, 2026. In order to maintain the maximum collateral agreement, the Company must remain compliant with a minimum liquidity test and a maximum net leverage ratio, as measured each quarter. The minimum liquidity test requires the Company to maintain liquidity at the greater of $400 million or the difference between the penal sum of all surety bonds and the amount of collateral posted in favor of surety providers, which was $508.6 million at June 30, 2024. The Company must also maintain a maximum net leverage ratio of 1.5 to 1.0, where the numerator consists of its funded debt, net of cash, and the denominator consists of its Adjusted EBITDA for the trailing twelve months. For purposes of calculating the ratio, only 50% of the outstanding principal amount of the Company’s 3.250% Convertible Senior Notes due March 2028 (the 2028 Convertible Notes) is deemed to be funded debt. The Company’s ability to pay dividends and make share repurchases is also subject to the quarterly minimum liquidity test. The Company is in compliance with such requirements at June 30, 2024.

Credit Support Facilities

In December 2023, the Company established cash-backed bank guarantee facilities, primarily to support Australian reclamation bonding requirements. The Company receives a variable deposit rate on the amount of cash collateral posted in support of the bank guarantee facilities, which mature at various dates between 2026 and 2029. At June 30, 2024, the bank guarantee facilities were backed by cash of $179.5 million.

Revolving Credit Facility

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Indebtedness

The Company’s total indebtedness as of June 30, 2024 and December 31, 2023 is presented in the table below.


Debt Instrument (defined below, as applicable)	June 30, 2024		December 31, 2023
	(Dollars in millions)






3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0


Finance lease obligations	24.5		22.3
Less: Debt issuance costs	(7.2)		(8.1)
	337.3		334.2
Less: Current portion of long-term debt	14.1		13.5
Long-term debt	$	323.2	$	320.7

The Company’s indebtedness requires estimated contractual principal and interest payments, assuming interest rates in effect at June 30, 2024, of approximately $16 million in 2024, $18 million in 2025, $16 million in 2026, $13 million in 2027 and $326 million in 2028.

Cash payments for interest related to the Company’s indebtedness and financial assurance instruments amounted to $24.1 million and $41.9 million during the six months ended June 30, 2024 and 2023, respectively.

2028 Convertible Notes

The 2028 Convertible Notes will mature on March 1, 2028, unless earlier converted, redeemed or repurchased in accordance with their terms. The 2028 Convertible Notes bear interest at a rate of 3.250% per year payable semi-annually in arrears on March 1 and September 1 of each year.

Accounts Receivable Securitization Program

As described in Note 12. “Financial Instruments and Other Guarantees” of the accompanying unaudited condensed consolidated financial statements, the Company entered into an accounts receivable securitization program during 2017. The securitization program was amended in February 2023 to increase the available funding capacity from $175.0 million to $225.0 million and adjust the relevant interest rate for borrowings to a SOFR plus an applicable margin. Funding capacity is limited to the availability of eligible receivables and is accounted for as a secured borrowing. Funding capacity under the program may also be utilized for letters of credit in support of other obligations, which has been the Company’s primary utilization. At June 30, 2024, the Company had no outstanding borrowings and $56.2 million of letters of credit outstanding under the program. The Company was not required to post cash collateral under the securitization program at June 30, 2024.

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Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2024.

Cash Flows

The following table summarizes the Company’s cash flows for the six months ended June 30, 2024 and 2023, as reported in the accompanying unaudited condensed consolidated financial statements. Available Free Cash Flow is a financial measure not recognized in accordance with U.S. GAAP. Refer to the “Reconciliation of Non-GAAP Financial Measures” section above for definitions and reconciliations to the most comparable measures under U.S. GAAP.


	Six Months Ended June 30,
	2024		2023
	(Dollars in millions)
Net cash provided by operating activities	$	126.8	$	739.7
Net cash used in investing activities	(316.8)		(120.0)
Net cash used in financing activities	(140.5)		(225.4)
Net change in cash, cash equivalents and restricted cash	(330.5)		394.3
Cash, cash equivalents and restricted cash at beginning of period	1,650.2		1,417.6
Cash, cash equivalents and restricted cash at end of period	$	1,319.7	$	1,811.9




Available Free Cash Flow	$	(225.6)

Operating Activities. The decrease in net cash provided by operating activities for the six months ended June 30, 2024 compared to the same period in the prior year was driven by a year-over-year decrease in operating cash flow from working capital ($461.9 million), primarily attributable to income tax payments and accruals ($191.3 million), an increase in accounts receivable due to timing of sales and overall higher price per ton ($176.6 million) and Shoal Creek inventories build due to the Demopolis Lock outage that continued through May 2024 ($55.0 million); the prior year receipt of cash related to variation margin requirements associated with derivative financial instruments ($198.0 million); and lower cash generated from mining operations. These unfavorable variances were partially offset by a decrease in cash used for collateral requirements ($266.5 million).

Investing Activities. The increase in net cash used in investing activities for the six months ended June 30, 2024 compared to the same period in the prior year was driven by the acquisition of Wards Well ($143.8 million) and higher capital expenditures and payments of capital accruals ($53.0 million).

Financing Activities. The decrease in net cash used by financing activities for the six months ended June 30, 2024 compared to the same period in the prior year was primarily driven by a decrease in common stock repurchases ($89.9 million), partially offset by an increase in dividends paid ($8.3 million).

Off-Balance-Sheet Arrangements

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The following table summarizes the Company’s financial instruments that carry off-balance-sheet risk.


	June 30, 2024
	Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	934.0	$	108.1	$	1,042.1
Letters of credit (2)	52.5		101.7		154.2
	986.5		209.8		1,196.3
Less: Letters of credit in support of surety bonds (3)	(52.5)		(14.5)		(67.0)
Obligations supported, net	$	934.0	$	195.3	$	1,129.3

(2) Amounts do not include cash-collateralized letters of credit.

(3) Certain letters of credit serve as collateral for surety bonds at the request of surety bond providers.

Not presented in the above table is $825.1 million of restricted cash and other balances serving as collateral which are included in the accompanying condensed consolidated balance sheets at June 30, 2024, as described in Note 12. “Financial Instruments and Other Guarantees” of the accompanying unaudited condensed consolidated financial statements. Such collateral is primarily in support of the financial instruments noted above, including in relation to the Company’s surety bond portfolio, its collateralized letter of credit agreement, its bank guarantee facilities and amounts held directly with beneficiaries which are not supported by surety bonds. The restricted cash and collateral balance at June 30, 2024 decreased from $957.6 million at December 31, 2023 due to collateral releases related to reductions in reclamation bonding requirements, replacement of cash-collateralized letters of credit with letters of credit under the new revolving credit facility and the impact of foreign currency rate changes.

At June 30, 2024, the Company had total asset retirement obligations of $699.9 million. Bonding requirement amounts may differ significantly from the related asset retirement obligation because such requirements are calculated under the assumption that reclamation begins currently, whereas the Company’s accounting liabilities are discounted from the end of a mine’s economic life (when final reclamation work would begin) to the balance sheet date.

As noted above, the Company’s reclamation bonding requirements decreased during the six months ended June 30, 2024 primarily due to an approximate $110 million reduction in U.S. reclamation bonding requirements. At June 30, 2024, the Company’s reclamation bonding requirements were supported by approximately $720 million of restricted cash and other balances serving as collateral, which exceeds the financial liability for final mine reclamation as calculated in accordance with U.S. GAAP.

Critical Accounting Policies and Estimates

The Company’s discussion and analysis of its financial condition, results of operations, liquidity and capital resources is based upon its financial statements, which have been prepared in accordance with U.S. GAAP. The Company is also required under U.S. GAAP to make estimates and judgments that affect the reported amounts of assets, liabilities, revenue and expenses and related disclosure of contingent assets and liabilities. On an ongoing basis, the Company evaluates its estimates. The Company bases its estimates on historical experience and on various other assumptions that it believes are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates.

At June 30, 2024, the Company identified certain assets with an aggregate carrying value of approximately $214 million in its Other U.S. Thermal segment whose recoverability is most sensitive to customer concentration risk.

The Company’s critical accounting policies and estimates are discussed in Part II, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in its Annual Report on Form 10-K for the year ended December 31, 2023. The Company’s critical accounting policies remain unchanged at June 30, 2024, and there have been no material changes in the Company’s critical accounting estimates.

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Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented

See Note 2. “Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented” to the Company’s unaudited condensed consolidated financial statements for a discussion of newly adopted accounting standards and accounting standards not yet implemented.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Coal Pricing Risk

The Company predominantly manages its commodity price risk for its non-trading, long-term coal contract portfolio through the use of long-term coal supply agreements (those with terms longer than one year) to the extent possible, rather than through the use of derivative instruments. As of June 30, 2024, the Company had approximately 100 million tons of U.S. thermal coal priced and committed for 2024. This includes approximately 85 million tons of PRB coal and 15 million tons of other U.S. thermal coal. The Company has the flexibility to increase volumes should demand warrant. Peabody is estimating full year 2024 thermal coal sales volumes from its Seaborne Thermal segment of 15.7 million to 16.2 million tons comprised of thermal export volume of 9.8 million to 10.3 million tons and domestic volume of 5.9 million tons. Peabody is estimating full year 2024 metallurgical coal sales from its Seaborne Metallurgical segment of 7.2 million to 7.6 million tons. Sales commitments in the metallurgical coal market are typically not long-term in nature, and the Company is therefore subject to fluctuations in market pricing. The Company’s sensitivity to market pricing in thermal coal markets is dependent on the duration of contracts.

As of June 30, 2024, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures and forwards.

Foreign Currency Risk

The Company utilizes options and collars to hedge currency risk associated with anticipated Australian dollar operating expenditures. The accounting for these derivatives is discussed in Note 6. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements. As of June 30, 2024, the Company held average rate options with an aggregate notional amount of $455.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar operating expenditures over the nine-month period ending March 31, 2025. As of June 30, 2024, the Company also held purchased collars with an aggregate notional amount of $507.0 million Australian dollars related to anticipated Australian dollar operating expenditures during the nine-month period ending March 31, 2025. Assuming the Company had no foreign currency hedging instruments in place, its exposure in operating costs and expenses due to a $0.10 change in the Australian dollar/U.S. dollar exchange rate is approximately $205 million to $215 million for the next twelve months. Based upon the Australian dollar/U.S. dollar exchange rate at June 30, 2024, the currency option contracts outstanding at that date would limit the Company’s exposure to approximately $154 million with respect to a $0.10 increase in the exchange rate, while the Company would benefit by approximately $203 million with respect to a $0.10 decrease in the exchange rate for the next twelve months.

Although Peabody believes its Australian dollar monetary asset position acts as a hedge to lessen the impact on its results from operations, the Company may continue to use options and collars to hedge its cash flow exposure to currency risk associated with anticipated Australian dollar operating expenditures.

Diesel Fuel Price Risk

The Company expects to consume 85 to 95 million gallons of diesel fuel during the next twelve months. A $10 per barrel change in the price of crude oil (the primary component of a refined diesel fuel product) would increase or decrease its annual diesel fuel costs by approximately $21 million based on its expected usage.

As of June 30, 2024, the Company did not have any diesel fuel derivative instruments in place. The Company partially manages the price risk of diesel fuel through the use of cost pass-through contacts with certain customers.

Interest Rate Risk

Peabody’s objectives in managing exposure to interest rate changes are to limit the impact of interest rate changes on earnings and cash flows and to lower overall borrowing costs. Peabody is primarily exposed to interest rate risk as a result of its interest-earning cash balances.

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Peabody’s interest-earning cash and restricted cash balances are primarily held in deposit accounts and investments with maturities of three months or less. Therefore, these balances are subject to interest rate fluctuations and could produce less income if interest rates fall. Based upon its interest-earning cash and restricted cash balances at June 30, 2024, a one percentage point decrease in interest rates would result in a decrease of approximately $13 million to interest income for the next twelve months.

Item 4. Controls and Procedures.

The Company’s disclosure controls and procedures are designed to, among other things, provide reasonable assurance that material information, both financial and non-financial, and other information required under the securities laws to be disclosed is accumulated and communicated to senior management, including its principal executive and financial officers, on a timely basis. The Company’s Chief Executive Officer and Chief Financial Officer have evaluated its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of June 30, 2024, and concluded that such controls and procedures were effective to provide reasonable assurance that the desired control objectives were achieved. Additionally, there have been no changes to the Company’s internal control over financial reporting during the most recent fiscal quarter that materially affected, or are reasonably likely to materially affect, its internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings.

The Company is subject to various legal and regulatory proceedings. For a description of its significant legal proceedings refer to Note 13. “Commitments and Contingencies” to the unaudited condensed consolidated financial statements included in Part I, Item 1. “Financial Statements” of this Quarterly Report, which information is incorporated by reference herein.

Item 1A. Risk Factors.

The Company operates in a rapidly changing environment that involves a number of risks. The risk factor set forth below is in addition to the risk factors previously disclosed in Item 1A. “Risk Factors” of Part I of its Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 23, 2024.

Peabody’s information and operational technology systems have been and in the future may be adversely affected by disruptions, damage, failure and risks associated with implementation and integration, including of new technologies.

Peabody could be adversely affected by system or network disruptions if new or upgraded information or operational technology systems are defective, not installed properly or not properly integrated into its operations. System modification failures could have a material adverse effect on the Company’s business, financial position and results of operations and could, if not successfully implemented, adversely impact the effectiveness of its internal control over financial reporting.

Further, Peabody increasingly depends on its information technology infrastructure for electronic communications among its operations, personnel, customers and suppliers around the world, including as a result of remote working and flexible working arrangements. These information technology systems, some of which are managed by third parties that the Company does not control, may be susceptible to damage, disruptions or shutdowns because of failures during the process of upgrading or replacing software, databases or components thereof, cutover activities in its restructuring and simplification initiatives, power outages, hardware failures, telecommunication failures, human errors, catastrophic events or other problems.

For information regarding other factors that could affect the Company's results of operations, financial condition and liquidity, see the risk factors disclosed in Item 1A. “Risk Factors” of Part I of its Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 23, 2024. In addition to the other information set forth in this Quarterly Report, including the information presented in Part I, Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” you should carefully consider the risk factors disclosed in the aforementioned filings, which could materially affect the Company’s results of operations, financial condition and liquidity.

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Factors that could affect the Company’s results or an investment in the Company’s securities include, but are not limited to:

•the Company’s profitability depends upon the prices it receives for its coal;

•if a substantial number of the Company’s long-term coal supply agreements, including those with its largest customers, terminate, or if the pricing, volumes or other elements of those agreements materially adjust, its revenue and operating profits could suffer if the Company is unable to find alternate buyers willing to purchase its coal on comparable terms to those in its contracts;

•risks inherent to mining could increase the cost of operating the Company’s business, and events and conditions that could occur during the course of its mining operations could have a material adverse impact on the Company;

•the Company’s take-or-pay arrangements could unfavorably affect its profitability;

•the Company may not recover its investments in its mining, exploration and other assets, which may require the Company to recognize impairment charges related to those assets;

•the Company’s ability to operate effectively could be impaired if it loses key personnel or fails to attract qualified personnel;

•the Company could be negatively affected if it fails to maintain satisfactory labor relations;

•the Company could be adversely affected if it fails to appropriately provide financial assurances for its obligations;

•if the assumptions underlying the Company’s asset retirement obligations for reclamation and mine closures are materially inaccurate, its costs could be significantly greater than anticipated;

•the Company’s mining operations are extensively regulated, which imposes significant costs on it, and future regulations and developments could increase those costs or limit its ability to produce coal;

•the Company’s operations may impact the environment or cause exposure to hazardous substances, and its properties may have environmental contamination, which could result in material liabilities to the Company;

•the Company may be unable to obtain, renew or maintain permits necessary for its operations, or the Company may be unable to obtain, renew or maintain such permits without conditions on the manner in which it runs its operations, which would reduce its production, cash flows and profitability;

•concerns about the impacts of coal combustion on global climate are increasingly leading to conditions that have affected and could continue to affect demand for the Company’s products or its securities and its ability to produce, including increased governmental regulation of coal combustion and unfavorable investment decisions by electricity generators;

•numerous activist groups are devoting substantial resources to anti-coal activities to minimize or eliminate the use of coal as a source of electricity generation, domestically and internationally, thereby further reducing the demand and pricing for coal, and potentially materially and adversely impacting the Company’s future financial results, liquidity and growth prospects;

•the Company’s trading and hedging activities do not cover certain risks and may expose it to earnings volatility and other risks;

•the Company’s future success depends upon its ability to continue acquiring and developing coal reserves and resources that are economically recoverable;

•the Company faces numerous uncertainties in estimating its coal reserves and resources and inaccuracies in its estimates could result in lower than expected revenue, higher than expected costs and decreased profitability;

•joint ventures, partnerships or non-managed operations may not be successful and may not comply with the Company’s operating standards;

•the Company’s expenditures for postretirement benefit obligations could be materially higher than it has predicted if its underlying assumptions prove to be incorrect;

•high inflation could continue to result in higher costs and decreased profitability;

•the Company’s business, results of operations, financial condition and prospects could be materially and adversely affected by pandemic or other widespread illnesses and the related effects on public health;

•Peabody is exposed to risks associated with political or international conflicts;

•Peabody could be exposed to significant liability, reputational harm, loss of revenue, increased costs or other risks if it sustains cybersecurity attacks or other security breaches that disrupt its operations or result in the dissemination of proprietary or confidential information about the Company, its customers or other third-parties;

•the Company is subject to various general operating risks which may be fully or partially outside of its control;

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•the Company may be able to incur more debt, including secured debt, which could increase the risks associated with its indebtedness;

•the terms of the agreements and instruments governing the Company’s debt and surety bonding obligations impose restrictions that may limit its operating and financial flexibility;

•the number and quantity of viable financing and insurance alternatives available to the Company may be significantly impacted by unfavorable lending and investment policies by financial institutions and insurance companies associated with concerns about environmental impacts of coal combustion, and negative views around its efforts with respect to environmental and social matters and related governance considerations could harm the perception of the Company by a significant number of investors or result in the exclusion of its securities from consideration by those investors;

•the price of Peabody’s securities may be volatile;

•Peabody’s common stock is subject to dilution and may be subject to further dilution in the future;

•there may be circumstances in which the interests of a significant stockholder could be in conflict with other stakeholders’ interests;

•the future payment of dividends on Peabody’s stock or future repurchases of its stock is dependent on a number of factors and cannot be assured;

•the Company may not be able to fully utilize its deferred tax assets;

•acquisitions and divestitures are a potentially important part of the Company’s long-term strategy, subject to its investment criteria, and involve a number of risks, any of which could cause the Company not to realize the anticipated benefits;

•Peabody’s certificate of incorporation and by-laws include provisions that may discourage a takeover attempt;

•diversity in interpretation and application of accounting literature in the mining industry may impact the Company’s reported financial results; and

•other risks and factors detailed in this report, including, but not limited to, those discussed in “Legal Proceedings,” set forth in Part II, Item 1 of this Quarterly Report on Form 10-Q.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

Share Repurchase Program

On April 17, 2023, the Company announced that its Board of Directors authorized a new share repurchase program (2023 Repurchase Program) authorizing repurchases of up to $1.0 billion of its common stock.

Under the 2023 Repurchase Program, the Company may purchase shares of common stock from time to time at the discretion of management through open market purchases, privately negotiated transactions, block trades, accelerated or other structured share repurchase programs or other means. The amount of any share repurchase transactions is subject to the Company’s annual AFCF. The manner, timing, and pricing of any share repurchase transactions will be based on a variety of factors, including market conditions, applicable legal requirements and alternative opportunities that the Company may have for the use or investment of capital. Through June 30, 2024, the Company had repurchased 19.3 million shares of its common stock under the 2023 Repurchase Program for $430.8 million, which included commissions paid of $0.4 million, leaving $569.6 million available for share repurchase. On August 1, 2024, the Company announced that it committed an additional $100 million for share repurchases.

Dividends

During the three and six months ended June 30, 2024, the Company declared dividends per share of $0.075 and $0.150, respectively. On August 1, 2024, the Company declared an additional dividend per share of $0.075 to be paid on September 4, 2024 to shareholders of record as of August 15, 2024. The declaration and payment of dividends and the amount of dividends will depend on the Company’s annual AFCF.

Share Relinquishments

The Company routinely allows employees to relinquish Common Stock to pay estimated taxes upon the vesting of restricted stock units and the payout of performance units that are settled in Common Stock under its equity incentive plans. The value of Common Stock tendered by employees is determined based on the closing price of the Company’s Common Stock on the dates of the respective relinquishments.

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Purchases of Equity Securities

The following table summarizes all share purchases for the three months ended June 30, 2024:


Period	Total Number of Shares Purchased (1)	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program	Maximum Dollar Value that May Yet Be Used to Repurchase Shares Under the Publicly Announced Program (In millions)
April 1 through April 30, 2024	1,129	$	23.70	—	$	569.6
May 1 through May 31, 2024	—	—		—	569.6
June 1 through June 30, 2024	28,611	24.78		—	569.6
Total	29,740	24.74		—

(1)Includes shares withheld to cover the withholding taxes upon the vesting of equity awards, which are not part of the publicly announced repurchase programs.

Item 4. Mine Safety Disclosures.

Peabody’s “Safety and Sustainability Management System” has been designed to set clear and consistent expectations for safety, health and environmental stewardship across the Company’s business. It aligns to the National Mining Association’s CORESafety® framework and encompasses three fundamental areas: leadership and organization, risk management and assurance. Peabody also partners with other companies and certain governmental agencies to pursue new technologies that have the potential to improve its safety performance and provide better safety protection for employees.

Peabody continually monitors its safety performance and regulatory compliance. The information concerning mine safety violations or other regulatory matters required by SEC regulations is included in Exhibit 95 to this Quarterly Report on Form 10-Q.

Item 5. Other Information.

Securities Trading Plans of Directors and Executive Officers

During the three months ended June 30, 2024, none of Peabody’s directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as defined in Item 408 of Regulation S-K of the Exchange Act.

Frequency of Future Non-Binding Stockholder Advisory Votes on Executive Compensation

As previously reported in a Current Report on Form 8-K filed on May 9, 2024, at the Company’s 2024 Annual Meeting of Stockholders held on May 9, 2024, the Company’s stockholders approved, on a non-binding advisory basis, the holding of a non-binding stockholder advisory vote on executive compensation annually. Based on this voting result, among other factors, the Company will include a non-binding stockholder advisory vote on executive compensation in its proxy materials annually until the next required stockholder vote on the frequency of such non-binding advisory votes on executive compensation.

Item 6. Exhibits.

See Exhibit Index on following pages.

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EXHIBIT INDEX

The exhibits below are numbered in accordance with the Exhibit Table of Item 601 of Regulation S-K.


Exhibit No.						Description of Exhibit
31.1†						Certification of periodic financial report by the Registrant’s Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934, as amended pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2†						Certification of periodic financial report by the Registrant’s Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934, as amended pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1†						Certification of periodic financial report pursuant to 18 U.S.C. Section 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by the Registrant’s Chief Executive Officer.

32.2†						Certification of periodic financial report pursuant to 18 U.S.C. Section 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by the Registrant’s Chief Financial Officer.

95†						Mine Safety Disclosure required by Item 104 of Regulation S-K.

101.INS						Inline XBRL Instance Document - the instance document does not appear in the interactive data file because XBRL tags are embedded within the Inline XBRL document

101.SCH						Inline XBRL Taxonomy Extension Schema Document

101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document

104						Cover Page Interactive Data File (embedded within the Inline XBRL document).

†						Filed herewith.

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SIGNATURE

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

PEABODY ENERGY CORPORATION

Date:

August 8, 2024

By:

/s/ MARK A. SPURBECK

Mark A. Spurbeck

Executive Vice President and Chief Financial Officer
(On behalf of the registrant and as Principal Financial Officer)

Exhibit 31.1

CERTIFICATION

I, James C. Grech, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Peabody Energy Corporation (“the registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 8, 2024

/s/ James C. Grech

James C. Grech

President and Chief Executive Officer

Exhibit 31.2

CERTIFICATION

I, Mark A. Spurbeck, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Peabody Energy Corporation (“the registrant”);

(b)any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 8, 2024

/s/ Mark A. Spurbeck

Mark A. Spurbeck

Executive Vice President and Chief Financial Officer

Exhibit 32.1

CERTIFICATION PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

(18 U.S.C. SECTION 1350)

I, James C. Grech, President and Chief Executive Officer of Peabody Energy Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2024 (the “Periodic Report”) which this statement accompanies fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)information contained in the Periodic Report fairly presents, in all material respects, the financial condition and results of operations of Peabody Energy Corporation.

Dated: August 8, 2024

/s/ James C. Grech

James C. Grech

President and Chief Executive Officer

Exhibit 32.2

CERTIFICATION PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

(18 U.S.C. SECTION 1350)

I, Mark A. Spurbeck, Executive Vice President and Chief Financial Officer of Peabody Energy Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(2)information contained in the Periodic Report fairly presents, in all material respects, the financial condition and results of operations of Peabody Energy Corporation.

Dated: August 8, 2024

/s/ Mark A. Spurbeck

Mark A. Spurbeck

Executive Vice President and Chief Financial Officer

Exhibit 95

Mine Safety Disclosures

The following disclosures are provided pursuant to Securities and Exchange Commission (SEC) regulations, which require certain disclosures by companies required to file periodic reports under the Securities Exchange Act of 1934, as amended, that operate coal mines regulated under the Federal Mine Safety and Health Act of 1977 (the Mine Act). The disclosures reflect United States (U.S.) mining operations only, as these requirements do not apply to our mines operated outside the U.S.

Mine Safety Information. Whenever the Mine Safety and Health Administration (MSHA) believes that a violation of the Mine Act, any health or safety standard, or any regulation has occurred, it may issue a violation which describes the associated condition or practice and designates a timeframe within which the operator must abate the violation. In some situations, such as when MSHA believes that conditions pose a hazard to miners, MSHA may issue an order removing miners from the area of the mine affected by the condition until hazards are corrected. Whenever MSHA issues a citation or order, it generally proposes a civil penalty, or fine, as a result of the violation that the operator is ordered to pay. Citations and orders can be contested and appealed and, as part of that process, are often reduced in severity and amount, and are sometimes vacated. The number of citations, orders and proposed assessments vary depending on the size and type (underground or surface) of the company and mine. Since MSHA is a branch of the U.S. Department of Labor, its jurisdiction applies only to our U.S. mines. As such, the mine safety disclosures that follow contain no information for our Australian mines.

The tables that follow reflect citations and orders issued to us by MSHA during the three and six months ended June 30, 2024, as reflected in our systems. The tables include only those mines that were issued orders or citations during the periods presented and, commensurate with SEC regulations, do not reflect orders or citations issued to independent contractors working at our mines. Due to timing and other factors, our data may not agree with the mine data retrieval system maintained by MSHA. The proposed assessments for the three and six months ended June 30, 2024 were taken from the MSHA system as of August 5, 2024.

Additional information about MSHA references used in the tables is as follows:

•Section 104 S&S Violations: The total number of violations received from MSHA under section 104(a) of the Mine Act that could significantly and substantially contribute to a serious injury if left unabated.

•Section 104(b) Orders: The total number of orders issued by MSHA under section 104(b) of the Mine Act, which represents a failure to abate a citation under section 104(a) within the period of time prescribed by MSHA. This results in an order of immediate withdrawal from the area of the mine affected by the condition until MSHA determines that the violation has been abated.

•Section 104(d) Citations and Orders: The total number of citations and orders issued by MSHA under section 104(d) of the Mine Act for unwarrantable failure to comply with mandatory health or safety standards.

•Section 104(e) Notices: The total number of notices issued by MSHA under section 104(e) of the Mine Act for a pattern of violations that could contribute to mine health or safety hazards.

•Section 110(b)(2) Violations: The total number of flagrant violations issued by MSHA under section 110(b)(2) of the Mine Act.

•Section 107(a) Orders: The total number of orders issued by MSHA under section 107(a) of the Mine Act for situations in which MSHA determined an imminent danger existed.

•Proposed MSHA Assessments: The total dollar value of proposed assessments from MSHA.

•Fatalities: The total number of mining-related fatalities.

Three Months Ended June 30, 2024


	Section 104 S&S Violations	Section 104(b) Orders	Section 104(d) Citations and Orders	Section 104(e) Pattern of Violations	Section 110(b)(2) Violations	Section 107(a) Orders	($) Proposed MSHA Assessments
Mine (1)								Fatalities
							(In thousands)
Seaborne Metallurgical
Shoal Creek Mine	39	—	—	—	—	—	60.0	—
Powder River Basin

North Antelope Rochelle	4	—	—	—	—	—	54.7	—

Other U.S. Thermal



Bear Run	—	—	—	—	—	—	0.2	—
El Segundo	1	—	—	—	—	—	—	—

Francisco Underground	7	—	—	—	—	—	12.7	—

Gateway North	18	—	—	—	—	—	85.7	—

Kayenta	—	—	—	—	—	—	0.7	—
Lee Ranch	3	—	—	—	—	—	—	—



Twentymile (Foidel Creek Mine)	6	—	—	—	—	—	19.3	—
Wild Boar	1	—	—	—	—	—	—	—

(1)The definition of "mine" under section 3 of the Mine Act includes the mine, as well as other items used in, or to be used in, or resulting from, the work of extracting coal, such as land, structures, facilities, equipment, machines, tools and coal preparation facilities. Also, there are instances where the mine name per the MSHA system differs from the mine name utilized by us. Where applicable, we have parenthetically listed the name of the mine per the MSHA system. Also, all U.S. mines are listed alphabetically within each of our mining segments.

Six Months Ended June 30, 2024


	Section 104 S&S Violations	Section 104(b) Orders	Section 104(d) Citations and Orders	Section 104(e) Pattern of Violations	Section 110(b)(2) Violations	Section 107(a) Orders	($) Proposed MSHA Assessments
Mine (1)								Fatalities
							(In thousands)
Seaborne Metallurgical
Shoal Creek Mine	98	—	2	—	—	—	214.1	—
Powder River Basin
Caballo	2	—	—	—	—	—	4.4	—
North Antelope Rochelle	16	—	3	—	—	—	273.0	—

Other U.S. Thermal
Bear Run	1	—	—	—	—	—	2.8	—
El Segundo	1	—	—	—	—	—	—	—

Francisco Underground	19	—	—	—	—	—	57.0	—

Gateway North	29	—	—	—	—	—	167.6	—
Gateway Preparation Plant	—	—	—	—	—	—	0.3	—
Kayenta	—	—	—	—	—	—	1.2	—
Lee Ranch	3	—	—	—	—	—	—	—



Twentymile (Foidel Creek Mine)	29	—	—	—	—	—	131.9	—
Wild Boar	1	—	—	—	—	—	0.6	—

Pending Legal Actions. The Federal Mine Safety and Health Review Commission (the Commission) is an independent adjudicative agency that provides administrative trial and appellate review of legal disputes arising under the Mine Act. These cases may involve, among other questions, challenges by operators to citations, orders and penalties they have received from MSHA, or complaints of discrimination by miners under section 105 of the Mine Act. The following is a brief description of the types of legal actions that may be brought before the Commission.

•Contests of Citations and Orders: A contest proceeding may be filed with the Commission by operators, miners or miners’ representatives to challenge the issuance of a citation or order issued by MSHA, including citations related to disputed provisions of operators' emergency response plans.

•Contests of Proposed Penalties (Petitions for Assessment of Penalties): A contest of a proposed penalty is an administrative proceeding before the Commission challenging a civil penalty that MSHA has proposed for the violation. Such proceedings may also involve appeals of judges' decisions or orders to the Commission on proposed penalties, including petitions for discretionary review and review by the Commission on its own motion.

•Complaints for Compensation: A complaint for compensation may be filed with the Commission by miners entitled to compensation when a mine is closed by certain withdrawal orders issued by MSHA. The purpose of the proceeding is to determine the amount of compensation, if any, due miners idled by the orders.

•Complaints of Discharge, Discrimination or Interference: A discrimination proceeding is a case that involves a miner’s allegation that he or she has suffered a wrong by the operator because he or she engaged in some type of activity protected under the Mine Act, such as making a safety complaint. This category includes temporary reinstatement proceedings, which involve cases in which a miner has filed a complaint with MSHA stating he or she has suffered discrimination and the miner has lost his or her position.

•Applications for Temporary Relief: An application for temporary relief from any modification or termination of any order or from any order issued under certain subparts of section 104 of the Mine Act may be filed with the Commission at any time before such order becomes final.

The table that follows presents information by mine regarding pending legal actions before the Commission at June 30, 2024. Each legal action is assigned a docket number by the Commission and may have as its subject matter one or more citations, orders, penalties or complaints.


	Pending Legal Actions						Legal Actions Initiated During the Three Months Ended June 30, 2024	Legal Actions Resolved During the Three Months Ended June 30, 2024
	Number of Pending Legal Actions as of June 30, 2024	Pre-Penalty Contests of Citations/Orders	Contests of Penalty Assessment(2)	Complaints for Compensation	Complaints of Discharge, Discrimination or Interference	Applications for Temporary Relief
Mine (1)

Seaborne Metallurgical
Shoal Creek Mine	10	—	10	—	—	—	4	5
Powder River Basin
Caballo	1	—	—	—	1	—	—	—
North Antelope Rochelle	3	—	3	—	—	—	2	3
Other U.S. Thermal





El Segundo	2	—	2	—	—	—	1	—
Francisco Underground	2	—	2	—	—	—	1	2
Gateway North	8	—	8	—	—	—	5	2



Twentymile (Foidel Creek)	5	—	5	—	—	—	2	3

(2)Contests included a total of 1 appeal of judge's decisions or orders to the Commission as of June 30, 2024.

Cover Page - shares shares in Millions	6 Months Ended
Cover Page - shares shares in Millions	Jun. 30, 2024	Aug. 02, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2024
Document Transition Report	false
Entity File Number	1-16463
Entity Registrant Name	PEABODY ENERGY CORP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	13-4004153
Entity Address, Address Line One	701 Market Street,
Entity Address, City or Town	St. Louis,
Entity Address, State or Province	MO
Entity Address, Postal Zip Code	63101-1826
City Area Code	314
Local Phone Number	342-3400
Title of 12(b) Security	Common Stock, par value $0.01 per share
Trading Symbol	BTU
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		125.9
Entity Central Index Key	0001064728
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q2
Amendment Flag	false

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Income Statement [Abstract]
Revenues	$ 1,042.0	$ 1,268.8	$ 2,025.6	$ 2,632.8
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	803.9	862.0	1,618.1	1,708.6
Depreciation, depletion and amortization	82.9	80.6	162.7	156.9
Asset retirement obligation expenses	12.9	15.5	25.8	30.9
Selling and administrative expenses	22.1	21.7	44.1	44.5
Restructuring charges	0.1	2.0	0.2	2.1
Other operating (income) loss:
Net gain on disposals	(7.5)	(5.2)	(9.6)	(7.1)
Asset impairment	0.0	0.0	0.0	2.0
Provision for NARM and Shoal Creek losses	1.9	33.7	3.7	33.7
Shoal Creek insurance recovery	(109.5)	0.0	(109.5)	0.0
Loss (income) from equity affiliates	1.3	(2.3)	5.0	(4.1)
Operating profit	233.9	260.8	285.1	665.3
Interest expense, net of capitalized interest	10.7	13.3	25.4	31.7
Net loss on early debt extinguishment	0.0	2.0	0.0	8.8
Interest income	(16.8)	(23.1)	(36.0)	(36.2)
Net periodic benefit credit, excluding service cost	(10.2)	(9.7)	(20.3)	(19.4)
Income from continuing operations before income taxes	250.2	278.3	316.0	680.4
Income tax provision	39.4	74.2	59.5	192.2
Income from continuing operations, net of income taxes	210.8	204.1	256.5	488.2
Loss from discontinued operations, net of income taxes	(1.6)	(1.3)	(2.3)	(2.6)
Net income	209.2	202.8	254.2	485.6
Less: Net income attributable to noncontrolling interests	9.8	23.6	15.2	37.9
Net income attributable to common stockholders	$ 199.4	$ 179.2	$ 239.0	$ 447.7
Income from continuing operations:
Basic income per share	$ 1.59	$ 1.27	$ 1.90	$ 3.14
Diluted income per share	1.43	1.16	1.72	2.85
Net income attributable to common stockholders:
Basic income per share	1.58	1.26	1.88	3.12
Diluted income per share	$ 1.42	$ 1.15	$ 1.70	$ 2.83

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Comprehensive Income [Abstract]
Net income	$ 209.2	$ 202.8	$ 254.2	$ 485.6
Postretirement plans (net of $0.0 tax provisions in each period)	(13.3)	(13.4)	(26.5)	(26.8)
Foreign currency translation adjustment	0.5	(0.4)	(1.4)	(0.6)
Other comprehensive loss, net of income taxes	(12.8)	(13.8)	(27.9)	(27.4)
Comprehensive income	196.4	189.0	226.3	458.2
Less: Net income attributable to noncontrolling interests	9.8	23.6	15.2	37.9
Comprehensive income attributable to common stockholders	$ 186.6	$ 165.4	$ 211.1	$ 420.3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Comprehensive Income [Abstract]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Current assets
Cash and cash equivalents	$ 621.7	$ 969.3
Accounts receivable, net of allowance for credit losses of $0.0 at June 30, 2024 and December 31, 2023	511.6	389.7
Inventories, net	422.1	351.8
Other current assets	296.8	308.9
Total current assets	1,852.2	2,019.7
Property, plant, equipment and mine development, net	3,003.1	2,844.1
Operating lease right-of-use assets	114.1	61.9
Restricted cash and collateral	825.1	957.6
Investments and other assets	83.8	78.8
Total assets	5,878.3	5,962.1
Current liabilities
Current portion of long-term debt	14.1	13.5
Accounts payable and accrued expenses	729.1	965.5
Total current liabilities	743.2	979.0
Long-term debt, less current portion	323.2	320.7
Deferred income taxes	47.3	28.6
Asset retirement obligations, less current portion	645.9	648.6
Accrued postretirement benefit costs	144.8	148.4
Operating lease liabilities, less current portion	88.2	47.7
Other noncurrent liabilities	170.7	181.6
Total liabilities	2,163.3	2,354.6
Stockholders’ equity
Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of June 30, 2024 and December 31, 2023	0.0	0.0
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of June 30, 2024 and December 31, 2023	0.0	0.0
Common Stock — $0.01 per share par value; 450.0 shares authorized, 189.1 shares issued and 125.9 shares outstanding as of June 30, 2024 and 188.6 shares issued and 128.7 shares outstanding as of December 31, 2023	1.9	1.9
Additional paid-in capital	3,987.2	3,983.0
Treasury stock, at cost — 63.2 and 59.9 common shares as of June 30, 2024 and December 31, 2023	(1,825.5)	(1,740.2)
Retained earnings	1,332.5	1,112.7
Accumulated other comprehensive income	161.7	189.6
Peabody Energy Corporation stockholders’ equity	3,657.8	3,547.0
Noncontrolling interests	57.2	60.5
Total stockholders’ equity	3,715.0	3,607.5
Total liabilities and stockholders’ equity	$ 5,878.3	$ 5,962.1
Treasury stock, shares (in shares)	63,200,000	59,900,000
Preferred Stock
Stockholders’ equity
Preferred stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	100,000,000.0	100,000,000.0
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Series Common Stock
Stockholders’ equity
Common stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	50,000,000.0	50,000,000.0
Common stock, shares issued (in shares)	0	0
Common stock, shares outstanding (in shares)	0	0
Common Stock
Stockholders’ equity
Common stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	450,000,000.0	450,000,000.0
Common stock, shares issued (in shares)	189,100,000	188,600,000
Common stock, shares outstanding (in shares)	125,900,000	128,700,000

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Current assets
Allowance for credit losses	$ 0.0	$ 0.0
Preferred Stock
Stockholders' equity
Preferred stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	100,000,000.0	100,000,000.0
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Series Common Stock
Stockholders' equity
Common stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	50,000,000.0	50,000,000.0
Common stock, shares issued (in shares)	0	0
Common stock, shares outstanding (in shares)	0	0
Common Stock
Stockholders' equity
Common stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	450,000,000.0	450,000,000.0
Common stock, shares issued (in shares)	189,100,000	188,600,000
Common stock, shares outstanding (in shares)	125,900,000	128,700,000

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2024	Jun. 30, 2023
Cash Flows From Operating Activities
Net income	$ 209.2	$ 254.2	$ 485.6
Loss from discontinued operations, net of income taxes	1.6	2.3	2.6
Income from continuing operations, net of income taxes	210.8	256.5	488.2
Adjustments to reconcile income from continuing operations, net of income taxes to net cash provided by operating activities:
Depreciation, depletion and amortization	82.9	162.7	156.9
Noncash interest expense, net		3.2	3.3
Deferred income taxes		18.7	65.0
Noncash share-based compensation		4.1	3.4
Asset impairment	0.0	0.0	2.0
Noncash provision for NARM and Shoal Creek losses		0.0	33.7
Net gain on disposals	(7.5)	(9.6)	(7.1)
Noncash income from port and rail capacity assignment		(0.3)	(9.2)
Net loss on early debt extinguishment	0.0	0.0	8.8
Loss (income) from equity affiliates	1.3	5.0	(4.1)
Foreign currency option contracts		3.3	(0.6)
Changes in current assets and liabilities:
Accounts receivable		(27.3)	149.3
Inventories		(70.4)	(20.8)
Other current assets		18.4	43.4
Accounts payable and accrued expenses		(234.0)	(23.3)
Collateral arrangements		149.6	(116.9)
Asset retirement obligations		(2.7)	3.6
Workers’ compensation obligations		(1.2)	(0.7)
Postretirement benefit obligations		(30.1)	(30.4)
Pension obligations		0.0	0.7
Other, net		(6.4)	0.0
Net cash provided by continuing operations		130.0	745.2
Net cash used in discontinued operations		(3.2)	(5.5)
Net cash provided by operating activities		126.8	739.7
Cash Flows From Investing Activities
Additions to property, plant, equipment and mine development		(167.0)	(122.3)
Changes in accrued expenses related to capital expenditures		(13.7)	(5.4)
Proceeds from Insurance Settlement, Investing Activities		5.6	0.0
Proceeds from disposal of assets, net of receivables		15.5	12.0
Contributions to joint ventures		(373.5)	(370.8)
Distributions from joint ventures		360.6	365.8
Other, net		(0.5)	0.7
Net cash used in investing activities		(316.8)	(120.0)
Cash Flows From Financing Activities
Repayments of long-term debt		(4.6)	(4.8)
Payment of debt issuance and other deferred financing costs		(11.1)	(0.3)
Common stock repurchases		(83.1)	(173.0)
Repurchase of employee common stock relinquished for tax withholding		(4.1)	(13.7)
Dividends paid		(19.1)	(10.8)
Distributions to noncontrolling interests		(18.5)	(22.8)
Net cash used in financing activities		(140.5)	(225.4)
Net change in cash, cash equivalents and restricted cash		(330.5)	394.3
Cash, cash equivalents and restricted cash at beginning of period (1)		1,650.2	1,417.6
Cash, cash equivalents and restricted cash at end of period (2)	1,319.7	1,319.7	1,811.9
Cash and cash equivalents	621.7	621.7
Restricted Cash	698.0	698.0
Shoal Creek insurance recovery	$ (109.5)	(109.5)	0.0
Asset Acquisition, Consideration Transferred		$ (143.8)	$ 0.0

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY - USD ($) $ in Millions	Total	Common Stock	Additional paid-in capital	Retained earnings	Accumulated other comprehensive income	Noncontrolling interests	Treasury Stock, Common
Balance, beginning of period at Dec. 31, 2022		$ 1.9	$ 3,975.9	$ 383.9	$ 242.5	$ 63.5	$ (1,372.9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividend equivalent units on dividends declared			0.1
Share-based compensation for equity-classified awards			3.4
Net income	$ 485.6			447.7		37.9
Dividends declared ($0.075, $0.075, $0.150 and $0.075 per share, respectively)				(10.9)
Common stock repurchases	173.0						173.0
Unsettled common stock repurchases							(11.2)
Sales and Excise Tax Payable							(1.6)
Repurchase of employee common stock relinquished for tax withholding	(13.7)						(13.7)
Postretirement plans (net of $0.0 tax provisions in each period)	(26.8)				(26.8)
Foreign currency translation adjustment	(0.6)				(0.6)
Distributions to noncontrolling interests						(22.8)
Balance, end of period at Jun. 30, 2023	3,523.3	1.9	3,979.4	820.7	215.1	78.6	(1,572.4)
Balance, beginning of period at Mar. 31, 2023		1.9	3,977.6	652.4	228.9	55.0	(1,386.1)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividend equivalent units on dividends declared			0.1
Share-based compensation for equity-classified awards			1.7
Net income	202.8			179.2		23.6
Dividends declared ($0.075, $0.075, $0.150 and $0.075 per share, respectively)				(10.9)
Common stock repurchases							173.0
Unsettled common stock repurchases							(11.2)
Sales and Excise Tax Payable							(1.6)
Repurchase of employee common stock relinquished for tax withholding							(0.5)
Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)				(13.4)
Foreign currency translation adjustment	(0.4)				(0.4)
Distributions to noncontrolling interests						0.0
Balance, end of period at Jun. 30, 2023	3,523.3	1.9	3,979.4	$ 820.7	215.1	78.6	(1,572.4)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared per share				$ 0.075
Balance, beginning of period at Dec. 31, 2023	3,607.5	1.9	3,983.0	$ 1,112.7	189.6	60.5	(1,740.2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividend equivalent units on dividends declared			0.1
Share-based compensation for equity-classified awards			4.1
Net income	254.2			239.0		15.2
Dividends declared ($0.075, $0.075, $0.150 and $0.075 per share, respectively)				(19.2)
Common stock repurchases	83.1						(83.1)
Unsettled common stock repurchases							2.6
Sales and Excise Tax Payable							(0.7)
Repurchase of employee common stock relinquished for tax withholding	(4.1)						(4.1)
Postretirement plans (net of $0.0 tax provisions in each period)	(26.5)				(26.5)
Foreign currency translation adjustment	(1.4)				(1.4)
Distributions to noncontrolling interests						(18.5)
Balance, end of period at Jun. 30, 2024	3,715.0	1.9	3,987.2	$ 1,332.5	161.7	57.2	(1,825.5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared per share				$ 0.150
Balance, beginning of period at Mar. 31, 2024		1.9	3,985.1	$ 1,142.5	174.5	47.4	(1,824.8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividend equivalent units on dividends declared			0.0
Share-based compensation for equity-classified awards			2.1
Net income	209.2			199.4		9.8
Dividends declared ($0.075, $0.075, $0.150 and $0.075 per share, respectively)				(9.4)
Common stock repurchases							0.0
Unsettled common stock repurchases							0.0
Sales and Excise Tax Payable							0.0
Repurchase of employee common stock relinquished for tax withholding							(0.7)
Postretirement plans (net of $0.0 tax provisions in each period)	(13.3)				(13.3)
Foreign currency translation adjustment	0.5				0.5
Distributions to noncontrolling interests						0.0
Balance, end of period at Jun. 30, 2024	$ 3,715.0	$ 1.9	$ 3,987.2	$ 1,332.5	$ 161.7	$ 57.2	$ (1,825.5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared per share				$ 0.075

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY (Parenthetical) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0
Retained earnings
Dividends declared per share	$ 0.075	$ 0.075	$ 0.150
Accumulated other comprehensive income
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0

Basis of Presentation	6 Months Ended
Basis of Presentation	Jun. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation The unaudited condensed consolidated financial statements include the accounts of Peabody Energy Corporation (PEC) and its consolidated subsidiaries and affiliates (along with PEC, the Company or Peabody). Interests in subsidiaries controlled by the Company are consolidated with any outside stockholder interests reflected as noncontrolling interests, except when the Company has an undivided interest in a joint venture. In those cases, the Company includes its proportionate share in the assets, liabilities, revenue and expenses of the jointly controlled entities within each applicable line item of the unaudited condensed consolidated financial statements. All intercompany transactions, profits and balances have been eliminated in consolidation. The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements and should be read in conjunction with the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023. In the opinion of management, these financial statements reflect all normal, recurring adjustments necessary for a fair presentation. Balance sheet information presented herein as of December 31, 2023 has been derived from the Company’s audited consolidated balance sheet at that date. The Company’s results of operations for the three and six months ended June 30, 2024 are not necessarily indicative of the results that may be expected for future quarters or for the year ending December 31, 2024.

Accounting Policies	6 Months Ended
Accounting Policies	Jun. 30, 2024
Accounting Policies [Abstract]
Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented	Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented Newly Adopted Accounting Standards The Company did not adopt any new accounting standards that had a material impact on its unaudited condensed consolidated financial statements or disclosures. Accounting Standards Not Yet Implemented Joint Ventures. In August 2023, Accounting Standards Update (ASU) 2023-05 was issued, which requires joint ventures to recognize and measure the initial contributions of monetary and nonmonetary assets and its net assets at fair value. The Company is required to apply the amendments for joint ventures with a formation date on or after January 1, 2025. A joint venture that was formed before January 1, 2025 may apply the amendments retrospectively. Segments. In November 2023, ASU 2023-07 was issued, which requires public entities to provide in interim periods all disclosures about a reportable segment’s profit or loss that are currently required annually; disclose significant expense categories and amounts that are easily computable from the management reports that are regularly provided to the chief operating decision maker (CODM); disclose how the CODM uses each reported measure to allocate resources; and disclose the name and title of the position of the individual identified as the CODM. The Company is required to adopt the amendments for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Company expects this ASU to only impact its disclosures with no impacts to its consolidated results of operations, cash flows and financial condition. Income Taxes. In December 2023, ASU 2023-09 was issued, which requires public entities to disclose more information primarily related to the income tax rate reconciliation and income taxes paid. The guidance also eliminates certain existing disclosure requirements related to uncertain tax positions and unrecognized deferred tax liabilities. The Company is required to adopt the amendments for fiscal years beginning after December 15, 2024. The amendments should be applied prospectively, with a retrospective option. Early adoption is permitted. The Company expects this ASU to only impact its disclosures with no impacts to its consolidated results of operations, cash flows and financial condition.

Revenue Recognition

6 Months Ended

Jun. 30, 2024

Revenue Recognition [Abstract]

Revenue Recognition

Disaggregation of Revenue


	Three Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	36.9	$	—	$	221.4	$	200.3	$	—	$	458.6
Export	270.6		—		—		—		—		270.6
Total thermal	307.5		—		221.4		200.3		—		729.2
Metallurgical coal

Export	—		294.0		—		—		—		294.0
Total metallurgical	—		294.0		—		—		—		294.0
Other (2)	—		0.3		0.5		1.7		16.3		18.8
Revenue	$	307.5	$	294.3	$	221.9	$	202.0	$	16.3	$	1,042.0


	Three Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	31.9	$	—	$	259.8	$	198.2	$	—	$	489.9
Export	367.5		—		—		—		—		367.5
Total thermal	399.4		—		259.8		198.2		—		857.4
Metallurgical coal

Export	—		371.6		—		—		—		371.6
Total metallurgical	—		371.6		—		—		—		371.6
Other (2)	0.1		0.9		(0.1)		1.7		37.2		39.8
Revenue	$	399.5	$	372.5	$	259.7	$	199.9	$	37.2	$	1,268.8


	Six Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	77.5	$	—	$	475.5	$	378.3	$	—	$	931.3
Export	513.7		—		—		—		—		513.7
Total thermal	591.2		—		475.5		378.3		—		1,445.0
Metallurgical coal

Export	—		538.0		—		—		—		538.0
Total metallurgical	—		538.0		—		—		—		538.0
Other (2)	0.2		3.3		0.5		15.3		23.3		42.6
Revenue	$	591.4	$	541.3	$	476.0	$	393.6	$	23.3	$	2,025.6


	Six Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	69.4	$	—	$	564.8	$	446.1	$	—	$	1,080.3
Export	676.3		—		—		—		—		676.3
Total thermal	745.7		—		564.8		446.1		—		1,756.6
Metallurgical coal

Export	—		658.8		—		—		—		658.8
Total metallurgical	—		658.8		—		—		—		658.8
Other (2)	0.3		2.1		0.2		3.2		211.6		217.4
Revenue	$	746.0	$	660.9	$	565.0	$	449.3	$	211.6	$	2,632.8

(1) Corporate and Other includes the following:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Unrealized gains on derivative contracts related to forecasted sales	$	—	$	40.3	$	—	$	159.0
Realized losses on derivative contracts related to forecasted sales	—		(30.3)		—		(80.9)
Revenue from physical sale of coal (3)	12.1		23.3		14.2		107.8
Trading revenue	—		0.1		—		0.1
Other (2)	4.2		3.8		9.1		25.6
Total Corporate and Other	$	16.3	$	37.2	$	23.3	$	211.6

Accounts Receivable

“Accounts receivable, net” at June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Trade receivables, net	$	355.8	$	322.3
Miscellaneous receivables, net	155.8		67.4
Accounts receivable, net	$	511.6	$	389.7

Inventories

6 Months Ended

Jun. 30, 2024

Inventory Disclosure [Abstract]

Inventories

“Inventories, net” as of June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Materials and supplies, net	$	169.2	$	153.0
Raw coal	122.6		105.6
Saleable coal	130.3		93.2
Inventories, net	$	422.1	$	351.8

Materials and supplies inventories, net presented above have been shown net of reserves of $6.6 million and $7.2 million as of June 30, 2024 and December 31, 2023, respectively.

Equity Method Investments

6 Months Ended

Jun. 30, 2024

Equity Method Investment, Summarized Financial Information [Abstract]

Equity Method Investments

The Company’s equity method investments include its interests in Middlemount Coal Pty Ltd (Middlemount), R3 Renewables LLC (R3) and certain other equity method investments.


					Loss (Income) from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2024		December 31, 2023		2024		2023		2024		2023
	(Dollars in millions)
Equity method investment related to Middlemount	$	43.0	$	42.5	$	(2.3)	$	(4.1)	$	(1.9)	$	(6.7)
Equity method investment related to R3	8.6		7.1		3.6		1.8		6.9		2.6

Total equity method investments	$	51.6	$	49.6	$	1.3	$	(2.3)	$	5.0	$	(4.1)

The Company contributed $8.4 million and $3.5 million to R3 during the six months ended June 30, 2024 and 2023, respectively.

Derivatives and Fair Value Measurements

6 Months Ended

Jun. 30, 2024

Fair Value Disclosures [Abstract]

Derivatives and Fair Value Measurements

Derivatives

Foreign Currency

Derivative Contracts Related to Forecasted Sales

As of June 30, 2024, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures and forwards.

Financial Trading Contracts

Tabular Derivatives Disclosures


		Three Months Ended June 30, 2024
		Total gain recognized in income		Loss realized in income on derivatives		Unrealized gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	0.8	$	(1.6)	$	2.4


Total		$	0.8	$	(1.6)	$	2.4

		Three Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(0.1)	$	(2.9)	$	2.8
Derivative contracts related to forecasted sales	Revenue	10.0		(30.3)		40.3
Financial trading contracts	Revenue	0.1		13.9		(13.8)
Total		$	10.0	$	(19.3)	$	29.3

		Six Months Ended June 30, 2024
		Total loss recognized in income		Loss realized in income on derivatives		Unrealized loss recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.7)	$	(2.4)	$	(3.3)


Total		$	(5.7)	$	(2.4)	$	(3.3)

		Six Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(5.8)	$	0.6
Derivative contracts related to forecasted sales	Revenue	78.1		(80.9)		159.0
Financial trading contracts	Revenue	0.1		31.2		(31.1)
Total		$	73.0	$	(55.5)	$	128.5

The Company classifies the cash effects of its derivatives within the “Cash Flows From Operating Activities” section of the unaudited condensed consolidated statements of cash flows.

Fair Value Measurements

The following tables set forth the hierarchy of the Company’s net asset positions for which fair value is measured on a recurring basis.


	June 30, 2024
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	2.2	$	—	$	2.2


Equity securities	0.8		—		—		0.8
Total net assets	$	0.8	$	2.2	$	—	$	3.0

	December 31, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	6.2	$	—	$	6.2


Equity securities	0.4		—		—		0.4
Total net assets	$	0.4	$	6.2	$	—	$	6.6

•Investments in equity securities are based on unadjusted quoted prices in active markets (Level 1).

Other Financial Instruments. The following methods and assumptions were used by the Company in estimating fair values for other financial instruments as of June 30, 2024 and December 31, 2023:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Total debt at par value	$	344.5	$	342.3
Less: Unamortized debt issuance costs	(7.2)		(8.1)
Net carrying amount	$	337.3	$	334.2

Estimated fair value	$	446.0	$	483.9

Property, Plant, Equipment and Mine Development

6 Months Ended

Jun. 30, 2024

Property, Plant and Equipment [Abstract]

Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of June 30, 2024 and December 31, 2023 is set forth in the table below:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Land and coal interests	$	2,624.0	$	2,475.2
Buildings and improvements	647.7		647.6
Machinery and equipment	1,943.5		1,787.6
Less: Accumulated depreciation, depletion and amortization	(2,212.1)		(2,066.3)
Property, plant, equipment and mine development, net	$	3,003.1	$	2,844.1

At-Risk Assets

Income Taxes	6 Months Ended
Income Taxes	Jun. 30, 2024
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	Income Taxes The Company's effective tax rate before remeasurement for the six months ended June 30, 2024 is based on the Company’s estimated full year effective tax rate, comprised of expected statutory tax provision, offset by foreign rate differential and changes in valuation allowance. The Company’s income tax provisions of $39.4 million and $74.2 million for the three months ended June 30, 2024 and 2023, respectively, included tax provisions of $1.9 million and $0.3 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax provisions of $59.5 million and $192.2 million for the six months ended June 30, 2024 and 2023, respectively, included a tax benefit of $3.9 million and a tax provision of $0.7 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s estimated full year pretax income and income tax expense are expected to be primarily generated in Australia. The Company recognizes interest and penalties related to unrecognized tax benefits in its income tax provision. During both the three and six months ended June 30, 2024, the Company’s net unrecognized tax benefits decreased by $1.3 million and its gross interest and penalties decreased by $6.1 million due to expiration of statutes.

Long-term Debt

6 Months Ended

Jun. 30, 2024

Debt Disclosure [Abstract]

Long-term Debt

The Company’s total indebtedness as of June 30, 2024 and December 31, 2023 consisted of the following:


Debt Instrument (defined below, as applicable)	June 30, 2024		December 31, 2023
	(Dollars in millions)






3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0


Finance lease obligations	24.5		22.3
Less: Debt issuance costs	(7.2)		(8.1)
	337.3		334.2
Less: Current portion of long-term debt	14.1		13.5
Long-term debt	$	323.2	$	320.7

2028 Convertible Notes

As of June 30, 2024, the if-converted value of the 2028 Convertible Notes exceeded the principal amount by $41.3 million.

Revolving Credit Facility

Interest Charges


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
2028 Convertible Notes	$	2.6	$	2.6	$	5.2	$	5.2
Finance lease obligations	0.5		0.4		0.9		0.9
Financial assurance instruments	6.1		8.0		14.9		20.0
Amortization of debt issuance costs	2.0		0.7		3.2		2.3
Capitalized interest	(1.7)		—		(1.7)		—
Other	1.2		1.6		2.9		3.3
Interest expense, net of capitalized interest	$	10.7	$	13.3	$	25.4	$	31.7

Cash paid for interest, net of capitalized interest	$	12.6	$	22.9	$	24.1	$	41.9
Non-cash interest expense	$	1.9	$	1.7	$	3.2	$	3.3

Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2024.

Pension and Postretirement Benefit Costs

6 Months Ended

Jun. 30, 2024

Retirement Benefits [Abstract]

Pension and Postretirement Benefit Costs

Net periodic pension cost included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)

Interest cost on projected benefit obligation	$	1.6	$	7.4	$	3.2	$	14.8
Expected return on plan assets	(1.2)		(6.6)		(2.4)		(13.2)

Net periodic pension cost	$	0.4	$	0.8	$	0.8	$	1.6

Net periodic postretirement benefit credit included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Service cost for benefits earned	$	0.1	$	0.2	$	0.2	$	0.3
Interest cost on accumulated postretirement benefit obligation	2.3		2.5		4.6		5.0
Expected return on plan assets	(0.1)		(0.2)		(0.2)		(0.3)
Amortization of prior service credit	(13.3)		(13.4)		(26.5)		(26.8)

Net periodic postretirement benefit credit	$	(11.0)	$	(10.9)	$	(21.9)	$	(21.8)

Earnings per Share (EPS)

6 Months Ended

Jun. 30, 2024

Earnings Per Share [Abstract]

Earnings per Share (EPS)

The following illustrates the earnings allocation method utilized in the calculation of basic and diluted EPS.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	201.0		180.5		241.3		450.3


Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)


Net income attributable to common stockholders	$	199.4	$	179.2	$	239.0	$	447.7

Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.0		3.5		6.1		6.1
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	204.0		184.0		247.4		456.4
Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)
Net income attributable to common stockholders	$	202.4	$	182.7	$	245.1	$	453.8

EPS denominator:
Weighted average shares outstanding — basic	126.0		142.3		127.0		143.4
Dilutive impact of share-based compensation awards	0.5		0.6		0.5		0.7
Dilutive impact of 2028 Convertible Notes	16.3		16.1		16.3		16.1
Weighted average shares outstanding — diluted	142.8		159.0		143.8		160.2

Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.59	$	1.27	$	1.90	$	3.14
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.58	$	1.26	$	1.88	$	3.12

Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.43	$	1.16	$	1.72	$	2.85
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.42	$	1.15	$	1.70	$	2.83

Financial Instruments and Other Guarantees

6 Months Ended

Jun. 30, 2024

Financial Instruments And Guarantees [Abstract]

Financial Instruments and Other Guarantees

The following table summarizes the Company’s financial instruments that carry off-balance-sheet risk.


	June 30, 2024
	Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	934.0	$	108.1	$	1,042.1
Letters of credit (2)	52.5		101.7		154.2
	986.5		209.8		1,196.3
Less: Letters of credit in support of surety bonds (3)	(52.5)		(14.5)		(67.0)
Obligations supported, net	$	934.0	$	195.3	$	1,129.3

(2) Amounts do not include cash-collateralized letters of credit.

(3) Certain letters of credit serve as collateral for surety bonds at the request of surety bond providers.

Surety Agreement Amendment and Collateral Requirements

LC Facility

Prior to its termination, undrawn letters of credit under the LC Facility bore interest at 6.00% per annum and unused commitments were subject to a 0.50% per annum commitment fee.

Accounts Receivable Securitization

Credit Support Facilities

Restricted Cash and Collateral


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	398.4	$	444.0
Credit support facilities (2)	299.6		236.9
	698.0		680.9
Other cash collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	127.1		276.7


	127.1		276.7
Restricted cash and collateral	$	825.1	$	957.6

Commitments and Contingencies	6 Months Ended
Commitments and Contingencies	Jun. 30, 2024
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Commitments Unconditional Purchase Obligations As of June 30, 2024, purchase commitments for capital expenditures were $90.9 million, all of which is obligated within the next two years, with $83.7 million obligated within the next 12 months. There were no other material changes to the Company’s commitments from the information provided in Note 21. “Commitments and Contingencies” to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023. Contingencies From time to time, the Company or its subsidiaries are involved in legal proceedings arising in the ordinary course of business or related to indemnities or historical operations. The Company believes it has recorded adequate reserves for these liabilities. The Company discusses its significant legal proceedings below, including ongoing proceedings and those that impacted the Company’s consolidated results of operations for the periods presented. Litigation and Matters Relating to Continuing Operations Metropolitan Mine Stormwater Discharge. Significantly high rainfall in New South Wales, including unprecedented rain totals at the Metropolitan Mine site resulted in stormwater being discharged from the mine site on several occasions in 2021 and 2022. On September 6, 2023, the Environment Protection Authority commenced a prosecution for five breaches of the Protection of the Environment Operations Act 1997 relating to the stormwater discharges. On March 15, 2024, the Company pled guilty to two of the charges related to water pollution, and two charges related to a failure to adequately maintain plant and equipment were consolidated into one charge to which the Company also pled guilty. No plea has been entered for the remaining charge that has been held over to a sentencing hearing that is scheduled for November 2024. Penalties will be determined at that sentencing hearing. During the six months ended June 30, 2024, the Company recorded an immaterial provision to establish a current liability that the Company believes is probable and reasonably estimable. Oregon Climate Change Lawsuit. On July 20, 2023, Peabody Energy was served with a summons issued on behalf of Multnomah County, Oregon. The complaint sought damages from the Company and other major energy producers for allegedly causing an “extreme heat event” in Multnomah County in late June and early July 2021. The causes of action, pursuant to Oregon state law, included a failure to warn, false or misleading advertisement and public nuisance. In July 2024, Peabody was dismissed from this case, without prejudice. Other At times, the Company becomes a party to other disputes, including those related to contract miner performance, claims, lawsuits, arbitration proceedings, regulatory investigations and administrative procedures in the ordinary course of business in the U.S., Australia and other countries where the Company does business. Based on current information, the Company believes that such other pending or threatened proceedings are likely to be resolved without a material adverse effect on its consolidated financial condition, results of operations or cash flows. The Company reassesses the probability and estimability of contingent losses as new information becomes available.

Segment Information

6 Months Ended

Jun. 30, 2024

Segment Reporting [Abstract]

Segment Information

Reportable segment results were as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	307.5	$	399.5	$	591.4	$	746.0
Seaborne Metallurgical	294.3		372.5		541.3		660.9
Powder River Basin	221.9		259.7		476.0		565.0
Other U.S. Thermal	202.0		199.9		393.6		449.3
Corporate and Other	16.3		37.2		23.3		211.6
Total	$	1,042.0	$	1,268.8	$	2,025.6	$	2,632.8

Adjusted EBITDA:
Seaborne Thermal	$	104.4	$	197.5	$	198.2	$	361.5


Seaborne Metallurgical	143.6		102.5		191.9		193.3
Powder River Basin	17.8		26.2		34.2		62.0
Other U.S. Thermal	35.4		51.9		81.9		116.1
Corporate and Other	8.5		(19.9)		(36.0)		15.9
Total	$	309.7	$	358.2	$	470.2	$	748.8

A reconciliation of consolidated income from continuing operations, net of income taxes to Adjusted EBITDA follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Depreciation, depletion and amortization	82.9		80.6		162.7		156.9
Asset retirement obligation expenses	12.9		15.5		25.8		30.9
Restructuring charges	0.1		2.0		0.2		2.1

Asset impairment	—		—		—		2.0
Provision for NARM and Shoal Creek losses	1.9		33.7		3.7		33.7
Shoal Creek insurance recovery - property damage	(28.7)		—		(28.7)		—
Changes in amortization of basis difference related to equity affiliates	(0.3)		(0.4)		(0.7)		(0.7)
Interest expense, net of capitalized interest	10.7		13.3		25.4		31.7
Net loss on early debt extinguishment	—		2.0		—		8.8
Interest income	(16.8)		(23.1)		(36.0)		(36.2)

Unrealized gains on derivative contracts related to forecasted sales	—		(40.3)		—		(159.0)
Unrealized (gains) losses on foreign currency option contracts	(2.4)		(2.8)		3.3		(0.6)

Take-or-pay contract-based intangible recognition	(0.8)		(0.6)		(1.5)		(1.2)
Income tax provision	39.4		74.2		59.5		192.2
Adjusted EBITDA	$	309.7	$	358.2	$	470.2	$	748.8

Other Events	6 Months Ended
Other Events	Jun. 30, 2024
Other Events [Abstract]
Other Events	Other Events Wards Well Acquisition The Company entered into a definitive agreement dated October 26, 2023, to acquire the southern part of the Wards Well tenements (Wards Well) which are adjacent to the Company’s Centurion Mine in Queensland, Australia. The acquisition, which was accounted for as an asset acquisition, was completed on April 16, 2024. The acquired asset was measured at the cost of the acquisition based on the total consideration, allocated on the basis of relative fair value. The total consideration of $153.4 million, consisting of cash consideration of $134.4 million, cash transaction costs of $9.4 million and the non-cash settlement of existing receivables with the acquiree of $9.6 million, was recorded in “Property, plant, equipment and mine development, net” in the condensed consolidated balance sheets as of June 30, 2024. The agreement also includes an initial contingent royalty of up to $200 million. The royalty will only be payable once the Company has recovered its investment and development costs of Wards Well and if the average sales price achieved exceeds certain thresholds. No royalty is payable if the Company does not commence mining Wards Well. The Company will adjust the cost basis of the assets acquired if and when the contingent royalty is paid or becomes payable. Share Repurchases During the six months ended June 30, 2024, the Company repurchased approximately 3.2 million shares of its common stock for $80.5 million, including commission fees. No shares were repurchased during the three months ended June 30, 2024. The Company had accrued excise taxes of $4.0 million related to share repurchases, which were unpaid at June 30, 2024. The Company includes commission fees and excise taxes, as incurred, with the cost of treasury stock. At June 30, 2024, $569.6 million remained available under its share repurchase program. North Antelope Rochelle Mine Tornado On June 23, 2023, the Company’s North Antelope Rochelle Mine sustained damage from a tornado which led to a temporary suspension of operations. The mine resumed operations on June 25, 2023. During the three and six months ended June 30, 2023, the Company recorded a provision for loss of $5.0 million related to the tornado damage, which included $4.0 million for materials and supplies inventories and $1.0 million for buildings and equipment. During the three and six months ended June 30, 2024, the Company recorded $1.9 million and $3.7 million, respectively, for incremental repair costs related to the tornado damage. Shoal Creek On March 29, 2023, the Company’s Shoal Creek Mine experienced a fire involving void fill material utilized to stabilize the roof structure of the mine. On June 20, 2023, the Company announced that the Shoal Creek Mine, in coordination with the Mine Safety and Health Administration, had safely completed localized sealing of the affected area of the mine. During the three and six months ended June 30, 2023, the Company recorded a provision for loss of $28.7 million related to the fire, which included $17.8 million related to longwall development and other costs and $10.9 million for equipment deemed inoperable within the affected area of the mine. In October 2023, the Company filed an insurance claim against applicable insurance policies with combined business interruption and property loss limits of $125 million above a $50 million deductible. During June 2024, the Company reached a settlement with its insurers and various re-insurers and recognized a $109.5 million insurance recovery which the Company included in its results of operations for the three and six months ended June 30, 2024. During the six months ended June 30, 2024, the Company collected $5.6 million of the insurance recovery. Since this portion of the recovery related to equipment damage for which the Company previously recognized the provision for loss, the Company has classified the amount within the “Cash Flows From Investing Activities” section of the unaudited condensed consolidated statements of cash flows. The remaining $103.9 million of the insurance recovery was recorded as a receivable within “Accounts receivable, net” in the condensed consolidated balance sheets as of June 30, 2024. Port and Rail Capacity Assignment During the six months ended June 30, 2023, the Company entered into an agreement to assign the right to its excess port and rail capacity related to its Centurion Mine to an unrelated party in exchange for $30.0 million Australian dollars. Half of such amount was received by the Company upon entry into the agreement, and half was payable in June 2024, subject to certain conditions. In connection with the transaction, the Company recorded revenue of $19.2 million during the six months ended June 30, 2023. In association with the completion of the Wards Well acquisition described above, the remaining receivable was settled as part of the consideration on April 16, 2024.

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Pay vs Performance Disclosure
Net Income (Loss)	$ 199.4	$ 179.2	$ 239.0	$ 447.7

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Jun. 30, 2024
Trading Arrangements, by Individual
Material Terms of Trading Arrangement	Securities Trading Plans of Directors and Executive Officers During the three months ended June 30, 2024, none of Peabody’s directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as defined in Item 408 of Regulation S-K of the Exchange Act.
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Derivative Instruments and Hedging Activities (Policies)	6 Months Ended
	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Corporate Hedging	From time to time, the Company may utilize various types of derivative instruments to manage its exposure to risks in the normal course of business, including (1) foreign currency exchange rate risk and the variability of cash flows associated with forecasted Australian dollar expenditures made in its Australian mining platform and (2) price risk of fluctuating coal prices related to forecasted sales or purchases of coal, or changes in the fair value of a fixed price physical sales contract. These risk management activities are actively monitored for compliance with the Company’s risk management policies. On a limited basis, the Company engages in the direct and brokered trading of coal and freight-related contracts. Except those contracts for which the Company has elected to apply a normal purchases and normal sales exception, all derivative coal trading contracts are accounted for at fair value.
Fair Value Transfer, Policy	The Company’s policy is to value all transfers between levels using the beginning of period valuation.

Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2024

Revenue Recognition [Abstract]

Disaggregation of Revenue by Product Type and Market

With respect to its seaborne reporting segments, the Company classifies as “Export” certain revenue from domestically-delivered coal under contracts in which the price is derived on a basis similar to export contracts.


	Three Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	36.9	$	—	$	221.4	$	200.3	$	—	$	458.6
Export	270.6		—		—		—		—		270.6
Total thermal	307.5		—		221.4		200.3		—		729.2
Metallurgical coal

Export	—		294.0		—		—		—		294.0
Total metallurgical	—		294.0		—		—		—		294.0
Other (2)	—		0.3		0.5		1.7		16.3		18.8
Revenue	$	307.5	$	294.3	$	221.9	$	202.0	$	16.3	$	1,042.0


	Three Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	31.9	$	—	$	259.8	$	198.2	$	—	$	489.9
Export	367.5		—		—		—		—		367.5
Total thermal	399.4		—		259.8		198.2		—		857.4
Metallurgical coal

Export	—		371.6		—		—		—		371.6
Total metallurgical	—		371.6		—		—		—		371.6
Other (2)	0.1		0.9		(0.1)		1.7		37.2		39.8
Revenue	$	399.5	$	372.5	$	259.7	$	199.9	$	37.2	$	1,268.8


	Six Months Ended June 30, 2024
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	77.5	$	—	$	475.5	$	378.3	$	—	$	931.3
Export	513.7		—		—		—		—		513.7
Total thermal	591.2		—		475.5		378.3		—		1,445.0
Metallurgical coal

Export	—		538.0		—		—		—		538.0
Total metallurgical	—		538.0		—		—		—		538.0
Other (2)	0.2		3.3		0.5		15.3		23.3		42.6
Revenue	$	591.4	$	541.3	$	476.0	$	393.6	$	23.3	$	2,025.6


	Six Months Ended June 30, 2023
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	69.4	$	—	$	564.8	$	446.1	$	—	$	1,080.3
Export	676.3		—		—		—		—		676.3
Total thermal	745.7		—		564.8		446.1		—		1,756.6
Metallurgical coal

Export	—		658.8		—		—		—		658.8
Total metallurgical	—		658.8		—		—		—		658.8
Other (2)	0.3		2.1		0.2		3.2		211.6		217.4
Revenue	$	746.0	$	660.9	$	565.0	$	449.3	$	211.6	$	2,632.8

(1) Corporate and Other includes the following:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Unrealized gains on derivative contracts related to forecasted sales	$	—	$	40.3	$	—	$	159.0
Realized losses on derivative contracts related to forecasted sales	—		(30.3)		—		(80.9)
Revenue from physical sale of coal (3)	12.1		23.3		14.2		107.8
Trading revenue	—		0.1		—		0.1
Other (2)	4.2		3.8		9.1		25.6
Total Corporate and Other	$	16.3	$	37.2	$	23.3	$	211.6

Schedule of Accounts Receivable

“Accounts receivable, net” at June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Trade receivables, net	$	355.8	$	322.3
Miscellaneous receivables, net	155.8		67.4
Accounts receivable, net	$	511.6	$	389.7

Inventories (Tables)

6 Months Ended

Jun. 30, 2024

Inventory Disclosure [Abstract]

Schedule of Inventories

“Inventories, net” as of June 30, 2024 and December 31, 2023 consisted of the following:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Materials and supplies, net	$	169.2	$	153.0
Raw coal	122.6		105.6
Saleable coal	130.3		93.2
Inventories, net	$	422.1	$	351.8

Receivables, Loans, Notes Receivable, and Others (Tables)

6 Months Ended

Jun. 30, 2024

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments


					Loss (Income) from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2024		December 31, 2023		2024		2023		2024		2023
	(Dollars in millions)
Equity method investment related to Middlemount	$	43.0	$	42.5	$	(2.3)	$	(4.1)	$	(1.9)	$	(6.7)
Equity method investment related to R3	8.6		7.1		3.6		1.8		6.9		2.6

Total equity method investments	$	51.6	$	49.6	$	1.3	$	(2.3)	$	5.0	$	(4.1)

Derivatives and Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2024

Fair Value Disclosures [Abstract]

Derivative Instruments, Gain (Loss)

The tables below show the amounts of pretax gains and losses related to the Company’s derivatives and their classification within the accompanying unaudited condensed consolidated statements of operations.


		Three Months Ended June 30, 2024
		Total gain recognized in income		Loss realized in income on derivatives		Unrealized gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	0.8	$	(1.6)	$	2.4


Total		$	0.8	$	(1.6)	$	2.4

		Three Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(0.1)	$	(2.9)	$	2.8
Derivative contracts related to forecasted sales	Revenue	10.0		(30.3)		40.3
Financial trading contracts	Revenue	0.1		13.9		(13.8)
Total		$	10.0	$	(19.3)	$	29.3

		Six Months Ended June 30, 2024
		Total loss recognized in income		Loss realized in income on derivatives		Unrealized loss recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.7)	$	(2.4)	$	(3.3)


Total		$	(5.7)	$	(2.4)	$	(3.3)

		Six Months Ended June 30, 2023
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(5.8)	$	0.6
Derivative contracts related to forecasted sales	Revenue	78.1		(80.9)		159.0
Financial trading contracts	Revenue	0.1		31.2		(31.1)
Total		$	73.0	$	(55.5)	$	128.5

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

The following tables set forth the hierarchy of the Company’s net asset positions for which fair value is measured on a recurring basis.


	June 30, 2024
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	2.2	$	—	$	2.2


Equity securities	0.8		—		—		0.8
Total net assets	$	0.8	$	2.2	$	—	$	3.0

	December 31, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	6.2	$	—	$	6.2


Equity securities	0.4		—		—		0.4
Total net assets	$	0.4	$	6.2	$	—	$	6.6

Carrying Amounts And Estimated Fair Values Of Companys Debt

The fair value of debt, shown below, is principally based on reported market values and estimates based on interest rates, maturities, credit risk, underlying collateral and completed market transactions.


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Total debt at par value	$	344.5	$	342.3
Less: Unamortized debt issuance costs	(7.2)		(8.1)
Net carrying amount	$	337.3	$	334.2

Estimated fair value	$	446.0	$	483.9

Property, Plant, Equipment and Mine Development (Tables)

6 Months Ended

Jun. 30, 2024

Property, Plant and Equipment [Abstract]

Schedule of Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of June 30, 2024 and December 31, 2023 is set forth in the table below:


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Land and coal interests	$	2,624.0	$	2,475.2
Buildings and improvements	647.7		647.6
Machinery and equipment	1,943.5		1,787.6
Less: Accumulated depreciation, depletion and amortization	(2,212.1)		(2,066.3)
Property, plant, equipment and mine development, net	$	3,003.1	$	2,844.1

Long-term Debt (Tables)

6 Months Ended

Jun. 30, 2024

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

The Company’s total indebtedness as of June 30, 2024 and December 31, 2023 consisted of the following:


Debt Instrument (defined below, as applicable)	June 30, 2024		December 31, 2023
	(Dollars in millions)






3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0


Finance lease obligations	24.5		22.3
Less: Debt issuance costs	(7.2)		(8.1)
	337.3		334.2
Less: Current portion of long-term debt	14.1		13.5
Long-term debt	$	323.2	$	320.7

Schedule of Interest Charges

Additionally, the table sets forth the amount of cash paid for interest, net of capitalized interest and the amount of non-cash interest expense primarily related to the amortization of debt issuance costs.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
2028 Convertible Notes	$	2.6	$	2.6	$	5.2	$	5.2
Finance lease obligations	0.5		0.4		0.9		0.9
Financial assurance instruments	6.1		8.0		14.9		20.0
Amortization of debt issuance costs	2.0		0.7		3.2		2.3
Capitalized interest	(1.7)		—		(1.7)		—
Other	1.2		1.6		2.9		3.3
Interest expense, net of capitalized interest	$	10.7	$	13.3	$	25.4	$	31.7

Cash paid for interest, net of capitalized interest	$	12.6	$	22.9	$	24.1	$	41.9
Non-cash interest expense	$	1.9	$	1.7	$	3.2	$	3.3

Pension and Postretirement Benefit Costs (Tables)

6 Months Ended

Jun. 30, 2024

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs

Net periodic pension cost included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)

Interest cost on projected benefit obligation	$	1.6	$	7.4	$	3.2	$	14.8
Expected return on plan assets	(1.2)		(6.6)		(2.4)		(13.2)

Net periodic pension cost	$	0.4	$	0.8	$	0.8	$	1.6

Net periodic postretirement benefit credit included the following components:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Service cost for benefits earned	$	0.1	$	0.2	$	0.2	$	0.3
Interest cost on accumulated postretirement benefit obligation	2.3		2.5		4.6		5.0
Expected return on plan assets	(0.1)		(0.2)		(0.2)		(0.3)
Amortization of prior service credit	(13.3)		(13.4)		(26.5)		(26.8)

Net periodic postretirement benefit credit	$	(11.0)	$	(10.9)	$	(21.9)	$	(21.8)

Earnings per Share (EPS) (Tables)

6 Months Ended

Jun. 30, 2024

Earnings Per Share [Abstract]

Earnings Allocation Method Utilized in the Calculation of Basic and Diluted EPS

The following illustrates the earnings allocation method utilized in the calculation of basic and diluted EPS.


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	201.0		180.5		241.3		450.3


Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)


Net income attributable to common stockholders	$	199.4	$	179.2	$	239.0	$	447.7

Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.0		3.5		6.1		6.1
Less: Net income attributable to noncontrolling interests	9.8		23.6		15.2		37.9
Income from continuing operations attributable to common stockholders	204.0		184.0		247.4		456.4
Loss from discontinued operations, net of income taxes	(1.6)		(1.3)		(2.3)		(2.6)
Net income attributable to common stockholders	$	202.4	$	182.7	$	245.1	$	453.8

EPS denominator:
Weighted average shares outstanding — basic	126.0		142.3		127.0		143.4
Dilutive impact of share-based compensation awards	0.5		0.6		0.5		0.7
Dilutive impact of 2028 Convertible Notes	16.3		16.1		16.3		16.1
Weighted average shares outstanding — diluted	142.8		159.0		143.8		160.2

Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.59	$	1.27	$	1.90	$	3.14
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.58	$	1.26	$	1.88	$	3.12

Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.43	$	1.16	$	1.72	$	2.85
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.02)
Net income attributable to common stockholders	$	1.42	$	1.15	$	1.70	$	2.83

Guarantees (Tables)

3 Months Ended

Jun. 30, 2024

Guarantees and Product Warranties [Abstract]

Financial Instruments and Guarantees with Off Balance Sheet Risk

The following table summarizes the Company’s financial instruments that carry off-balance-sheet risk.


	June 30, 2024
	Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	934.0	$	108.1	$	1,042.1
Letters of credit (2)	52.5		101.7		154.2
	986.5		209.8		1,196.3
Less: Letters of credit in support of surety bonds (3)	(52.5)		(14.5)		(67.0)
Obligations supported, net	$	934.0	$	195.3	$	1,129.3

(2) Amounts do not include cash-collateralized letters of credit.

(3) Certain letters of credit serve as collateral for surety bonds at the request of surety bond providers.

Restricted Cash and Collateral

The Company’s other cash collateral generally includes deposits held by regulatory authorities or financial institutions over which the Company has no control or ability to access.


	June 30, 2024		December 31, 2023
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	398.4	$	444.0
Credit support facilities (2)	299.6		236.9
	698.0		680.9
Other cash collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	127.1		276.7


	127.1		276.7
Restricted cash and collateral	$	825.1	$	957.6

Segment Information (Tables)

6 Months Ended

Jun. 30, 2024

Segment Reporting [Abstract]

Reportable Segment Results

Reportable segment results were as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	307.5	$	399.5	$	591.4	$	746.0
Seaborne Metallurgical	294.3		372.5		541.3		660.9
Powder River Basin	221.9		259.7		476.0		565.0
Other U.S. Thermal	202.0		199.9		393.6		449.3
Corporate and Other	16.3		37.2		23.3		211.6
Total	$	1,042.0	$	1,268.8	$	2,025.6	$	2,632.8

Adjusted EBITDA:
Seaborne Thermal	$	104.4	$	197.5	$	198.2	$	361.5


Seaborne Metallurgical	143.6		102.5		191.9		193.3
Powder River Basin	17.8		26.2		34.2		62.0
Other U.S. Thermal	35.4		51.9		81.9		116.1
Corporate and Other	8.5		(19.9)		(36.0)		15.9
Total	$	309.7	$	358.2	$	470.2	$	748.8

Reconciliation of Consolidated (Loss) Income from Continuing Operations, Net of Income Taxes to Adjusted EBITDA

A reconciliation of consolidated income from continuing operations, net of income taxes to Adjusted EBITDA follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	210.8	$	204.1	$	256.5	$	488.2
Depreciation, depletion and amortization	82.9		80.6		162.7		156.9
Asset retirement obligation expenses	12.9		15.5		25.8		30.9
Restructuring charges	0.1		2.0		0.2		2.1

Asset impairment	—		—		—		2.0
Provision for NARM and Shoal Creek losses	1.9		33.7		3.7		33.7
Shoal Creek insurance recovery - property damage	(28.7)		—		(28.7)		—
Changes in amortization of basis difference related to equity affiliates	(0.3)		(0.4)		(0.7)		(0.7)
Interest expense, net of capitalized interest	10.7		13.3		25.4		31.7
Net loss on early debt extinguishment	—		2.0		—		8.8
Interest income	(16.8)		(23.1)		(36.0)		(36.2)

Unrealized gains on derivative contracts related to forecasted sales	—		(40.3)		—		(159.0)
Unrealized (gains) losses on foreign currency option contracts	(2.4)		(2.8)		3.3		(0.6)

Take-or-pay contract-based intangible recognition	(0.8)		(0.6)		(1.5)		(1.2)
Income tax provision	39.4		74.2		59.5		192.2
Adjusted EBITDA	$	309.7	$	358.2	$	470.2	$	748.8

Revenue Recognition - Revenue by Product Type and Market (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Disaggregation of Revenue [Line Items]
Revenues	$ 1,042.0	$ 1,268.8	$ 2,025.6	$ 2,632.8
Other Income	4.2	3.8	9.1	25.6
Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	2.4	29.3	(3.3)	128.5
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(1.6)	(19.3)	(2.4)	(55.5)
Derivative, Gain (Loss) on Derivative, Net	0.8	10.0	(5.7)	73.0
Physical commodity purchase / sale contracts [Member] \| Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		40.3		159.0
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.0	(30.3)	0.0	(80.9)
Derivative, Gain (Loss) on Derivative, Net		10.0		78.1
Coal Contract [Member] \| Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		(13.8)		(31.1)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		13.9		31.2
Derivative, Gain (Loss) on Derivative, Net	0.0	0.1	0.0	0.1
Coal Contract and Physical commodity purchase / sale contracts \| Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	0.0	40.3	0.0	159.0
Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	729.2	857.4	1,445.0	1,756.6
Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	294.0	371.6	538.0	658.8
Other (2)
Disaggregation of Revenue [Line Items]
Revenues	18.8	39.8	42.6	217.4
Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	458.6	489.9	931.3	1,080.3
Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	270.6	367.5	513.7	676.3
Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	294.0	371.6	538.0	658.8
Seaborne Thermal
Disaggregation of Revenue [Line Items]
Revenues	307.5	399.5	591.4	746.0
Seaborne Thermal \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	307.5	399.4	591.2	745.7
Seaborne Thermal \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Seaborne Thermal \| Other (2)
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.1	0.2	0.3
Seaborne Thermal \| Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	36.9	31.9	77.5	69.4
Seaborne Thermal \| Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	270.6	367.5	513.7	676.3
Seaborne Thermal \| Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Seaborne Metallurgical
Disaggregation of Revenue [Line Items]
Revenues	294.3	372.5	541.3	660.9
Seaborne Metallurgical \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Seaborne Metallurgical \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	294.0	371.6	538.0	658.8
Seaborne Metallurgical \| Other (2)
Disaggregation of Revenue [Line Items]
Revenues	0.3	0.9	3.3	2.1
Seaborne Metallurgical \| Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Seaborne Metallurgical \| Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Seaborne Metallurgical \| Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	294.0	371.6	538.0	658.8
Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	221.9	259.7	476.0	565.0
Powder River Basin \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	221.4	259.8	475.5	564.8
Powder River Basin \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Powder River Basin \| Other (2)
Disaggregation of Revenue [Line Items]
Revenues	0.5	(0.1)	0.5	0.2
Powder River Basin \| Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	221.4	259.8	475.5	564.8
Powder River Basin \| Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Powder River Basin \| Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Other U.S. Thermal
Disaggregation of Revenue [Line Items]
Revenues	202.0	199.9	393.6	449.3
Other U.S. Thermal \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	200.3	198.2	378.3	446.1
Other U.S. Thermal \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Other U.S. Thermal \| Other (2)
Disaggregation of Revenue [Line Items]
Revenues	1.7	1.7	15.3	3.2
Other U.S. Thermal \| Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	200.3	198.2	378.3	446.1
Other U.S. Thermal \| Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Other U.S. Thermal \| Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Corporate and Other (1)
Disaggregation of Revenue [Line Items]
Revenues	16.3	37.2	23.3	211.6
Corporate and Other (1) \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Corporate and Other (1) \| Trading and Brokerage Coal Deliveries
Disaggregation of Revenue [Line Items]
Revenues	12.1	23.3	14.2	107.8
Corporate and Other (1) \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Corporate and Other (1) \| Other (2)
Disaggregation of Revenue [Line Items]
Revenues	16.3	37.2	23.3	211.6
Corporate and Other (1) \| Domestic \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Corporate and Other (1) \| Export \| Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	0.0	0.0	0.0
Corporate and Other (1) \| Export \| Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	$ 0.0	$ 0.0	$ 0.0	$ 0.0

Revenue Recognition - Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Revenue Recognition [Abstract]
Trade receivables, net	$ 355.8	$ 322.3
Miscellaneous receivables, net	155.8	67.4
Accounts receivable, net	$ 511.6	$ 389.7

Revenue Recognition - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
Revenue Recognition - Narrative (Details) - USD ($)	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Revenue Recognition [Abstract]
Accounts receivable, allowance for credit loss	$ 0		$ 0		$ 0
Accounts receivable, credit loss expense (reversal)	$ 0	$ 0	$ 0	$ 0

Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Inventory [Line Items]
Materials and supplies, net	$ 169.2	$ 153.0
Raw coal	122.6	105.6
Saleable coal	130.3	93.2
Inventories, net	$ 422.1	$ 351.8

Inventories Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Material and supplies
Inventory [Line Items]
inventory reserves	$ 6.6	$ 7.2

Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Equity Method Investments (Details) - USD ($) $ in Millions	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 51.6		$ 51.6		$ 49.6
Loss (income) from equity affiliates	1.3	$ (2.3)	5.0	$ (4.1)
Middlemount Mine
Schedule of Equity Method Investments [Line Items]
Equity method investments	43.0		43.0		42.5
Loss (income) from equity affiliates	(2.3)	(4.1)	(1.9)	(6.7)
R3 Renewables
Schedule of Equity Method Investments [Line Items]
Equity method investments	8.6		8.6		$ 7.1
Loss (income) from equity affiliates	$ 3.6	$ 1.8	$ 6.9	$ 2.6

Equity Method Investments Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2024	Jun. 30, 2023
R3 Renewables
Schedule of Equity Method Investments [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	$ 8.4	$ 3.5

Derivatives and Fair Value Measurements - Narrative (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024 USD ($) $ / $	Jun. 30, 2023 USD ($)	Jun. 30, 2024 USD ($) $ / $	Jun. 30, 2023 USD ($)	Jun. 30, 2024 AUD ($) $ / $	Dec. 31, 2023 USD ($)
Derivatives, Fair Value [Line Items]
Unobservable Measurement Input, Uncertainty, Description			10
Asset impairment	$ 0.0	$ 0.0	$ 0.0	$ 2.0
Fair Value, Inputs, Level 1, 2 and 3
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0.0	$ 0.0	$ 0.0	$ 0.0
Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Notional amount					$ 455,000,000.0
Foreign Exchange Contract [Member] \| Minimum
Derivatives, Fair Value [Line Items]
Derivative, exchange rate cap (in dollars per share) \| $ / $	0.70		0.70		0.70
Foreign Exchange Contract [Member] \| Maximum
Derivatives, Fair Value [Line Items]
Derivative, exchange rate cap (in dollars per share) \| $ / $	0.71		0.71		0.71
Foreign Exchange Contract [Member] \| Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 2.2		$ 2.2			$ 6.2
Coal derivative contracts related to forecasted sales
Derivatives, Fair Value [Line Items]
Notional amount					$ 0
Foreign Exchange Option
Derivatives, Fair Value [Line Items]
Notional amount					$ 507,000,000
Derivative, Floor Price					0.59
Derivative, Cap Price					0.72

Derivatives and Fair Value Measurements - Gains and Losses on Hedging Derivatives (Details) - Designated as Hedging Instrument - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0.8	$ 10.0	$ (5.7)	$ 73.0
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(1.6)	(19.3)	(2.4)	(55.5)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	2.4	29.3	(3.3)	128.5
Foreign Exchange Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.8	(0.1)	(5.7)	(5.2)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(1.6)	(2.9)	(2.4)	(5.8)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	2.4	2.8	(3.3)	0.6
Physical commodity purchase / sale contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		10.0		78.1
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.0	(30.3)	0.0	(80.9)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		40.3		159.0
Coal Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0.0	0.1	$ 0.0	0.1
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net		13.9		31.2
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		$ (13.8)		$ (31.1)

Derivatives and Fair Value Measurements - Financial Instruments Measured on Recurring Basis (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Derivative [Line Items]
Total net assets	$ 3.0	$ 6.6
Level 1
Derivative [Line Items]
Total net assets	0.8	0.4
Level 2
Derivative [Line Items]
Total net assets	2.2	6.2
Level 3
Derivative [Line Items]
Total net assets	0.0	0.0
Foreign Exchange Contract [Member]
Derivative [Line Items]
Total net assets	2.2	6.2
Foreign Exchange Contract [Member] \| Level 1
Derivative [Line Items]
Total net assets	0.0	0.0
Foreign Exchange Contract [Member] \| Level 2
Derivative [Line Items]
Total net assets	2.2	6.2
Foreign Exchange Contract [Member] \| Level 3
Derivative [Line Items]
Total net assets	0.0	0.0
Equity securities
Derivative [Line Items]
Total net assets	0.8	0.4
Equity securities \| Level 1
Derivative [Line Items]
Total net assets	0.8	0.4
Equity securities \| Level 2
Derivative [Line Items]
Total net assets	0.0	0.0
Equity securities \| Level 3
Derivative [Line Items]
Total net assets	$ 0.0	$ 0.0

Derivatives and Fair Value Measurements - Long-term debt (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt and Lease Obligation, Net	$ 337.3	$ 334.2
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt at par value	344.5	342.3
Less: Unamortized debt issuance costs	(7.2)	(8.1)
Debt and Lease Obligation, Net	337.3	334.2
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Estimated fair value	$ 446.0	$ 483.9

Property, Plant, Equipment and Mine Development (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
Less: Accumulated depreciation, depletion and amortization	$ (2,212.1)	$ (2,066.3)
Property, plant, equipment and mine development, net	3,003.1	2,844.1
Land and coal interests
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	2,624.0	2,475.2
Buildings and improvements
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	647.7	647.6
Machinery and equipment
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	$ 1,943.5	$ 1,787.6

Property, Plant, Equipment and Mine Development - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Impaired Long-Lived Assets Held and Used [Line Items]
At-risk assets	$ 214.0		$ 214.0
Asset impairment	$ 0.0	$ 0.0	$ 0.0	$ 2.0

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Income Taxes
Income tax provision (benefit)	$ 39.4	$ 74.2	$ 59.5	$ 192.2
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	1.3		6.1
Foreign Tax Authority
Income Taxes
Remeasurement of income tax	$ 1.9	$ 0.3	$ (3.9)	$ 0.7

Long-term Debt - Schedule of Debt (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Carrying amount
Debt Instrument [Line Items]
Less: Unamortized debt issuance costs	$ (7.2)		$ (7.2)		$ (8.1)
Total debt	337.3		337.3		334.2
Finance lease obligations	24.5		24.5		22.3
Total debt	337.3		337.3		334.2
Less: Current portion of long-term debt	14.1		14.1		13.5
Long-term debt	323.2		323.2		320.7
Interest expense, net of capitalized interest	10.7	$ 13.3	25.4	$ 31.7
Interest Paid, Capitalized, Investing Activities	12.6	22.9	24.1	41.9
Other Noncash Income (Expense)	1.9	1.7
Noncash interest expense, net			3.2	3.3
Interest Costs Capitalized	(1.7)	0.0	(1.7)	0.0
Financial assurance instruments
Debt Instrument [Line Items]
Interest expense, net of capitalized interest	6.1	8.0	14.9	20.0
Indebtedness
Debt Instrument [Line Items]
Interest expense, net of capitalized interest	2.6	2.6	5.2	5.2
Capital Lease Obligations
Debt Instrument [Line Items]
Interest expense, net of capitalized interest	0.5	0.4	0.9	0.9
Amortization of debt issuance costs
Debt Instrument [Line Items]
Interest expense, net of capitalized interest	2.0	0.7	3.2	2.3
Other
Debt Instrument [Line Items]
Interest expense, net of capitalized interest	1.2	$ 1.6	2.9	$ 3.3
Senior Notes \| 3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)
Debt Instrument [Line Items]
Long-term debt	$ 320.0		$ 320.0		$ 320.0
Stated interest rate	3.25%		3.25%

Long-term Debt - Narrative (Details)						3 Months Ended			6 Months Ended
Long-term Debt - Narrative (Details)	Jun. 05, 2024 $ / shares	May 02, 2024 $ / shares	Feb. 21, 2024 $ / shares	Jan. 18, 2024 USD ($)	Feb. 03, 2023	Jun. 30, 2024 USD ($) $ / shares	Jun. 30, 2023 USD ($) $ / shares	Jun. 30, 2022 USD ($) $ / shares	Jun. 30, 2024 USD ($) $ / shares	Jun. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)	Mar. 01, 2022 USD ($)
Debt Instrument [Line Items]
Interest expense, net of capitalized interest						$ 10,700,000	$ 13,300,000		$ 25,400,000	$ 31,700,000
Net loss on early debt extinguishment						0	2,000,000.0		0	8,800,000
Finance lease obligations						24,500,000			24,500,000		$ 22,300,000
Interest Paid, Capitalized, Investing Activities						12,600,000	$ 22,900,000		24,100,000	$ 41,900,000
2024 Credit Agreement Availability						$ 222,000,000			$ 222,000,000
Dividends declared per share \| $ / shares		$ 0.075
Common Stock, Dividends, Per Share, Cash Paid \| $ / shares	$ 0.075
Retained earnings
Debt Instrument [Line Items]
Dividends declared per share \| $ / shares						$ 0.075	$ 0.075		$ 0.150
Letter of Credit
Debt Instrument [Line Items]
Debt instrument, fronting fee				0.125%
Letters of credit outstanding, amount						$ 98,000,000			$ 98,000,000
Line of Credit Facility, Commitment Fee Percentage				0.50%	0.50%
Revolving credit facility
Debt Instrument [Line Items]
Debt issuance cost				$ 9,700,000
Line of credit facility, maximum borrowing capacity				$ 320,000,000
Maximum
Debt Instrument [Line Items]
Basis spread on variable rate				3.25%
Maximum \| Letter of Credit
Debt Instrument [Line Items]
Basis spread on variable rate				4.25%
Maximum \| Revolving credit facility
Debt Instrument [Line Items]
Basis spread on variable rate				4.25%
Minimum
Debt Instrument [Line Items]
Basis spread on variable rate				2.50%
Minimum \| Letter of Credit
Debt Instrument [Line Items]
Basis spread on variable rate				3.50%
Minimum \| Revolving credit facility
Debt Instrument [Line Items]
Basis spread on variable rate				3.50%
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)
Debt Instrument [Line Items]
Debt Instrument, Convertible, If-converted Value in Excess of Principal									$ 41,300,000
Senior Notes \| 3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)
Debt Instrument [Line Items]
Stated interest rate						3.25%			3.25%
Long-term debt						$ 320,000,000.0			$ 320,000,000.0		$ 320,000,000.0
Principal amount												$ 320,000,000
Debt Issuance Costs, Gross								$ 11,200,000
Debt Conversion, Converted Instrument, Rate						1.00%
Debt Instrument, Convertible, Conversion Ratio								50.3816
Debt Instrument, Convertible, Revised Conversion Ratio	51.2148		51.0440
Debt Instrument, Convertible, Conversion Price \| $ / shares			$ 19.59					$ 19.85
Debt Instrument, Principle Amount						$ 1,000			$ 1,000

Pension and Postretirement Benefit Costs - Schedule of Net Periodic Benefit (Benefit) Cost (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Defined Benefit Plan Disclosure [Line Items]
Net periodic pension cost	$ (10.2)	$ (9.7)	$ (20.3)	$ (19.4)
Defined benefit pension plans
Defined Benefit Plan Disclosure [Line Items]
Interest cost on projected benefit obligation	1.6	7.4	3.2	14.8
Expected return on plan assets	(1.2)	(6.6)	(2.4)	(13.2)
Net periodic pension cost	0.4	0.8	0.8	1.6
Postretirement benefit plans
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	0.1	0.2	0.2	0.3
Interest cost on projected benefit obligation	2.3	2.5	4.6	5.0
Expected return on plan assets	(0.1)	(0.2)	(0.2)	(0.3)
Amortization of prior service credit	(13.3)	(13.4)	(26.5)	(26.8)
Net periodic pension cost	$ (11.0)	$ (10.9)	$ (21.9)	$ (21.8)

Earnings per Share (EPS) - Calculation of Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Basic EPS numerator:
Income from continuing operations, net of income taxes	$ 210.8	$ 204.1	$ 256.5	$ 488.2
Less: Net income attributable to noncontrolling interests	9.8	23.6	15.2	37.9
Income from continuing operations attributable to common stockholders	201.0	180.5	241.3	450.3
Loss from discontinued operations, net of income taxes	(1.6)	(1.3)	(2.3)	(2.6)
Net income attributable to common stockholders	199.4	179.2	239.0	447.7
Diluted EPS numerator:
Income from continuing operations, net of income taxes	210.8	204.1	256.5	488.2
Interest on Convertible Debt, Net of Tax	(3.0)	(3.5)	(6.1)	(6.1)
Less: Net income attributable to noncontrolling interests	9.8	23.6	15.2	37.9
Net Income (Loss) from Continuing Operations Available to Common Shareholders, Diluted	204.0	184.0	247.4	456.4
Loss from discontinued operations, net of income taxes	(1.6)	(1.3)	(2.3)	(2.6)
Net Income (Loss) Available to Common Stockholders, Diluted	$ 202.4	$ 182.7	$ 245.1	$ 453.8
EPS denominator:
Weighted average shares outstanding — basic	126,000,000.0	142,300,000	127,000,000.0	143,400,000
Dilutive impact of share-based compensation awards	500,000	600,000	500,000	700,000
Dilutive impact of 2028 Convertible Notes	16,300,000	16,100,000	16,300,000	16,100,000
Weighted average shares outstanding — diluted	142,800,000	159,000,000.0	143,800,000	160,200,000
Basic EPS attributable to common stockholders:
Basic income per share	$ 1.59	$ 1.27	$ 1.90	$ 3.14
Loss from discontinued operations	(0.01)	(0.01)	(0.02)	(0.02)
Net income attribute to common stockholders per share	1.58	1.26	1.88	3.12
Diluted EPS attributable to common stockholders:
Income from continuing operations	1.43	1.16	1.72	2.85
Loss from discontinued operations	(0.01)	(0.01)	(0.02)	(0.02)
Net income attribute to common stockholders per share	$ 1.42	$ 1.15	$ 1.70	$ 2.83
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Dilutive impact of 2028 Convertible Notes	16,300,000	16,100,000	16,300,000	16,100,000
Impact of dilutive securities (in shares)	16,300,000	16,100,000	16,300,000	16,100,000
Net Income (Loss) from Continuing Operations Available to Common Shareholders, Diluted	$ 204.0	$ 184.0	$ 247.4	$ 456.4

Earnings per Share (EPS) - Narrative (Details) - shares	3 Months Ended		6 Months Ended
Earnings per Share (EPS) - Narrative (Details) - shares	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Earnings Per Share [Abstract]
Antidilutive shares excluded from EPS calculation (in shares)	100,000	100,000	100,000	100,000

Financial Instruments and Other Guarantees (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023	Mar. 31, 2023
Guarantee Obligations [Line Items]
Restricted Cash	$ 698.0	$ 680.9
Deposits Assets	127.1	276.7
Restricted cash and collateral	825.1	957.6
Surety Trust Account
Guarantee Obligations [Line Items]
Restricted Cash	398.4	444.0	$ 566.3
Deposits with Regulatory Authorities
Guarantee Obligations [Line Items]
Deposits Assets	127.1	276.7
Cash backed bank guarantees
Guarantee Obligations [Line Items]
Restricted Cash	299.6	$ 236.9
Asset Retirement Obligations
Guarantee Obligations [Line Items]
Surety bonds amount	934.0
Letters of credit outstanding, amount	52.5
Surety Bonds and Letters of Credit Outstanding for Reclamation Support	986.5
Less: Letters of Credit in Support of Surety Bonds	52.5
Total Obligations Supported, Net	934.0
Asset Retirement and Other Obligations
Guarantee Obligations [Line Items]
Surety bonds amount	1,042.1
Letters of credit outstanding, amount	154.2
Total Obligations Supported, Net	1,129.3
Total Surety Bonds and Letters of Credit Outstanding	1,196.3
Total Letters of Credit in Support of Surety Bonds	(67.0)
Other Obligations
Guarantee Obligations [Line Items]
Surety bonds amount	108.1
Letters of credit outstanding, amount	101.7
Less: Letters of Credit in Support of Surety Bonds	14.5
Total Obligations Supported, Net	195.3
Surety Bonds and Letters of Credit Outstanding for Other Support	209.8
Secured debt \| Accounts Receivable Securitization Program
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	56.2
Letter of Credit
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	98.0
Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	$ 116.6

Financial Instruments and Other Guarantees - Narratives (Details) - USD ($) $ in Millions			3 Months Ended		6 Months Ended
	Jan. 18, 2024	Feb. 03, 2023	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023	Apr. 14, 2023	Mar. 31, 2023	Feb. 13, 2023
Guarantee Obligations [Line Items]
Line of Credit Facility, Current Borrowing Capacity								$ 237.2
Net loss on early debt extinguishment			$ 0.0	$ 2.0	$ 0.0	$ 8.8
Interest expense, net of capitalized interest			10.7	13.3	25.4	31.7
Restricted Cash			698.0		698.0		$ 680.9
Difference between penal sum of all surety bonds and amount of collateral posted in favor of surety providers			508.6		508.6
Capitalized debt issuance costs related to bank guarantees					1.4
Cash-backed bank guarantee facilities			179.5		179.5
Letter of Credit
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount			98.0		98.0
Proceeds from Issuance of Debt		$ 324.0
Line of Credit Facility, Increase (Decrease), Net		$ (65.0)
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		6.00%
Line of Credit Facility, Commitment Fee Percentage	0.50%	0.50%
Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount			116.6		116.6
Line of credit facility, maximum borrowing capacity			$ 250.0		$ 250.0
Cash Collateral, Percentage of the aggregate amount of letters of credit outstanding			103.00%		103.00%
Cash-collateralized Letters of Credit			$ 120.1		$ 120.1
Stated interest rate			0.75%		0.75%
Surety Trust Account
Guarantee Obligations [Line Items]
Restricted Cash			$ 398.4		$ 398.4		$ 444.0		$ 566.3
Accounts Receivable Securitization Program
Guarantee Obligations [Line Items]
Line of Credit Facility, Previous Maximum Borrowing Capacity										$ 175.0
Line of credit facility, maximum borrowing capacity										$ 225.0
Accounts Receivable Securitization Program \| Secured debt
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount			56.2		$ 56.2
Basis spread on variable rate					2.10%
Maximum
Guarantee Obligations [Line Items]
Debt Instrument, Collateral Amount								$ 721.8
Basis spread on variable rate	3.25%
Maximum \| Letter of Credit
Guarantee Obligations [Line Items]
Basis spread on variable rate	4.25%
Maximum \| Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Transaction support agreements, additional collateral demands			5.0		$ 5.0
Minimum
Guarantee Obligations [Line Items]
Basis spread on variable rate	2.50%
Minimum \| Letter of Credit
Guarantee Obligations [Line Items]
Basis spread on variable rate	3.50%
Surety Bond
Guarantee Obligations [Line Items]
Debt Instrument, Transaction Support Agreements, Additional Collateral Posted									140.5
Debt Instrument, Transaction Support Agreement, Additional Collateral Held									$ 15.0
Surety Agreement Liquidity Covenant, Amount			$ 400.0		$ 400.0
Surety Bond \| Maximum
Guarantee Obligations [Line Items]
Net Leverage Ratio			1.5		1.5
Surety Bond \| Minimum
Guarantee Obligations [Line Items]
Net Leverage Ratio			1.0		1.0
Senior Notes \| 3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)
Guarantee Obligations [Line Items]
Debt Instrument, Funded, Percent			50.00%		50.00%
Stated interest rate			3.25%		3.25%
Secured debt \| Accounts Receivable Securitization Program
Guarantee Obligations [Line Items]
Outstanding borrowings			$ 0.0		$ 0.0
Accounts Receivable from Securitization			97.1		97.1
Interest expense, net of capitalized interest			$ 0.6	$ 0.8	$ 1.4	$ 1.9

Commitments and Contingencies (Details) - Capital Addition Purchase Commitments $ in Millions	Jun. 30, 2024 USD ($)
Long-term Purchase Commitment [Line Items]
Unrecorded unconditional purchase obligation (within next five years)	$ 90.9
Unrecorded unconditional purchase obligation (within next 12 months)	$ 83.7

Segment Information - Segment Results (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Reportable segment results
Revenues	$ 1,042.0	$ 1,268.8	$ 2,025.6	$ 2,632.8
Adjusted EBITDA	309.7	358.2	470.2	748.8
Seaborne Thermal
Reportable segment results
Revenues	307.5	399.5	591.4	746.0
Adjusted EBITDA	104.4	197.5	198.2	361.5
Seaborne Metallurgical
Reportable segment results
Revenues	294.3	372.5	541.3	660.9
Adjusted EBITDA	143.6	102.5	191.9	193.3
Powder River Basin
Reportable segment results
Revenues	221.9	259.7	476.0	565.0
Adjusted EBITDA	17.8	26.2	34.2	62.0
Other U.S. Thermal
Reportable segment results
Revenues	202.0	199.9	393.6	449.3
Adjusted EBITDA	35.4	51.9	81.9	116.1
Corporate and Other (1)
Reportable segment results
Revenues	16.3	37.2	23.3	211.6
Adjusted EBITDA	$ 8.5	$ (19.9)	$ (36.0)	$ 15.9

Segment Information - Reconciliation to Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Segment Reporting Information [Line Items]
Income from continuing operations, net of income taxes	$ 210.8	$ 204.1	$ 256.5	$ 488.2
Depreciation, depletion and amortization	82.9	80.6	162.7	156.9
Asset retirement obligation expenses	12.9	15.5	25.8	30.9
Restructuring charges	0.1	2.0	0.2	2.1
Asset impairment	0.0	0.0	0.0	2.0
Provision for NARM and Shoal Creek losses	1.9	33.7	3.7	33.7
Gain on Business Interruption Insurance Recovery	28.7	0.0	28.7	0.0
Changes in amortization of basis difference related to equity affiliates	(0.3)	(0.4)	(0.7)	(0.7)
Interest expense, net of capitalized interest	10.7	13.3	25.4	31.7
Net loss on early debt extinguishment	0.0	2.0	0.0	8.8
Interest income	(16.8)	(23.1)	(36.0)	(36.2)
Unrealized gains on derivative contracts related to forecasted sales	0.0	(40.3)	0.0	(159.0)
Unrealized (gains) losses on foreign currency option contracts	(2.4)	(2.8)	3.3	(0.6)
Take-or-pay contract-based intangible recognition	(0.8)	(0.6)	(1.5)	(1.2)
Income tax provision	39.4	74.2	59.5	192.2
Adjusted EBITDA	$ 309.7	$ 358.2	$ 470.2	$ 748.8

Other Events Narrative (Details) $ in Millions		1 Months Ended	3 Months Ended		6 Months Ended
Other Events Narrative (Details) $ in Millions	Apr. 16, 2024 USD ($)	Oct. 31, 2023 USD ($)	Jun. 30, 2024 USD ($) shares	Jun. 30, 2023 USD ($)	Jun. 30, 2024 USD ($) shares	Jun. 30, 2023 USD ($)	Jun. 30, 2023 AUD ($)
Other Commercial Events [Line Items]
Revenue from Collaborative Arrangement, Excluding Revenue from Contract with Customer							$ 30.0
Revenue related to excess port and rail capacity agreement						$ 19,200,000
Storm Damage Provision				$ 5,000,000		5,000,000
Common stock repurchase amount including commission fees					$ 80,500,000
Stock Repurchase Program, Remaining Authorized Repurchase Amount			$ 569,600,000		$ 569,600,000
Stock Repurchased During Period, Shares \| shares			0		3,200,000
Shoal Creek insurance recovery			$ (109,500,000)	0	$ (109,500,000)	0
Storm damage provision for materials and supplies inventories				4,000,000		4,000,000
Storm damage provision for buildings and equipment				1,000,000		1,000,000
Provision for Other Losses				28,700,000		28,700,000
Provision for other losses related to longwall development and other costs				17,800,000		17,800,000
Provision for other losses for equipment				$ 10,900,000		10,900,000
Proceeds from Insurance Settlement, Investing Activities					5,600,000	$ 0
Fair Value of Assets Acquired					153,400,000
Asset Acquisition, Consideration Transferred, Transaction Cost					9,400,000
Asset Acquisition, Consideration Transferred, Excluding Transaction Cost					134,400,000
Noncash or Part Noncash Acquisition, Value of Assets Acquired					9,600,000
Loss Contingency, Receivable			103,900,000		103,900,000
Wards Well coal deposit
Other Commercial Events [Line Items]
Contingent royalty	$ 200,000,000
Treasury Stock, Common
Other Commercial Events [Line Items]
Accrued excise taxes related to common stock repurchases			4,000,000		4,000,000
North Antelope Rochelle Mine
Other Commercial Events [Line Items]
Storm Damage Provision			$ 1,900,000		$ 3,700,000
Shoal Creek Mine
Other Commercial Events [Line Items]
Business interruption and property loss limits on insurance claim, amount		$ 125,000,000
Deductible amount		$ 50,000,000