10-Q

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, 2023

or

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

Commission File Number: 1-16463

____________________________________________

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 132.8 million shares of the registrant’s common stock (par value of $0.01 per share) outstanding at July 28, 2023.

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	27
Item 3. Quantitative and Qualitative Disclosures About Market Risk	47
Item 4. Controls and Procedures	47
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

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,
	2023		2022		2023		2022
	(Dollars in millions, except per share data)
Revenue	$	1,268.8	$	1,321.9	$	2,632.8	$	2,013.3
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	862.0		825.6		1,708.6		1,524.6
Depreciation, depletion and amortization	80.6		73.8		156.9		146.7
Asset retirement obligation expenses	15.5		12.7		30.9		27.7
Selling and administrative expenses	21.7		21.8		44.5		44.9
Restructuring charges	2.0		0.2		2.1		1.8
Other operating income:
Net gain on disposals	(5.2)		(12.8)		(7.1)		(17.7)
Asset impairment	—		—		2.0		—
Provision for NARM and Shoal Creek loss	33.7		—		33.7		—
Income from equity affiliates	(2.3)		(48.7)		(4.1)		(93.4)
Operating profit	260.8		449.3		665.3		378.7
Interest expense	13.3		37.6		31.7		77.0
Net loss on early debt extinguishment	2.0		2.3		8.8		25.8
Interest income	(23.1)		(0.9)		(36.2)		(1.4)
Net periodic benefit credit, excluding service cost	(9.7)		(12.3)		(19.4)		(24.5)
Income from continuing operations before income taxes	278.3		422.6		680.4		301.8
Income tax provision	74.2		11.3		192.2		10.3
Income from continuing operations, net of income taxes	204.1		411.3		488.2		291.5
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income	202.8		410.6		485.6		290.0
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Net income attributable to common stockholders	$	179.2	$	409.5	$	447.7	$	290.0
Income from continuing operations:
Basic income per share	$	1.27	$	2.85	$	3.14	$	2.08
Diluted income per share	$	1.16	$	2.55	$	2.85	$	1.93
Net income attributable to common stockholders:
Basic income per share	$	1.26	$	2.84	$	3.12	$	2.07
Diluted income per share	$	1.15	$	2.54	$	2.83	$	1.93

See accompanying notes to unaudited condensed consolidated financial statements.

1

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Net income	$	202.8	$	410.6	$	485.6	$	290.0
Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)		(13.5)		(26.8)		(26.9)
Foreign currency translation adjustment	(0.4)		(3.4)		(0.6)		(1.5)
Other comprehensive loss, net of income taxes	(13.8)		(16.9)		(27.4)		(28.4)
Comprehensive income	189.0		393.7		458.2		261.6
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Comprehensive income attributable to common stockholders	$	165.4	$	392.6	$	420.3	$	261.6

See accompanying notes to unaudited condensed consolidated financial statements.

2

PEABODY ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

	(Unaudited)
	June 30, 2023		December 31, 2022
	(Amounts in millions, except per share data)
ASSETS
Current assets
Cash and cash equivalents	$	1,080.5	$	1,307.3
Accounts receivable, net of allowance for credit losses of $0.0 at June 30, 2023 and December 31, 2022	325.5		465.5
Inventories, net	312.9		296.1
Other current assets	244.3		303.6
Total current assets	1,963.2		2,372.5
Property, plant, equipment and mine development, net	2,819.5		2,865.0
Operating lease right-of-use assets	27.2		26.9
Restricted cash and collateral	925.4		187.4
Investments and other assets	73.8		84.3
Deferred income taxes	19.0		74.7
Total assets	$	5,828.1	$	5,610.8
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current portion of long-term debt	$	13.0	$	13.2
Accounts payable and accrued expenses	892.1		905.5
Total current liabilities	905.1		918.7
Long-term debt, less current portion	321.5		320.6
Deferred income taxes	20.0		20.4
Asset retirement obligations	669.4		665.8
Accrued postretirement benefit costs	153.0		156.5
Operating lease liabilities, less current portion	11.7		11.0
Other noncurrent liabilities	224.1		223.0
Total liabilities	2,304.8		2,316.0
Stockholders’ equity
Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of June 30, 2023 and December 31, 2022	—		—
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of June 30, 2023 and December 31, 2022	—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 188.6 shares issued and 135.9 shares outstanding as of June 30, 2023 and 187.1 shares issued and 143.9 shares outstanding as of December 31, 2022	1.9		1.9
Additional paid-in capital	3,979.4		3,975.9
Treasury stock, at cost — 52.7 and 43.2 common shares as of June 30, 2023 and December 31, 2022	(1,572.4)		(1,372.9)
Retained earnings	820.7		383.9
Accumulated other comprehensive income	215.1		242.5
Peabody Energy Corporation stockholders’ equity	3,444.7		3,231.3
Noncontrolling interests	78.6		63.5
Total stockholders’ equity	3,523.3		3,294.8
Total liabilities and stockholders’ equity	$	5,828.1	$	5,610.8

See accompanying notes to unaudited condensed consolidated financial statements.

3

PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
	Six Months Ended June 30,
	2023		2022
	(Dollars in millions)
Cash Flows From Operating Activities
Net income	$	485.6	$	290.0
Loss from discontinued operations, net of income taxes	2.6		1.5
Income from continuing operations, net of income taxes	488.2		291.5
Adjustments to reconcile income from continuing operations, net of income taxes to net cash provided by operating activities:
Depreciation, depletion and amortization	156.9		146.7
Noncash interest expense, net	3.3		9.0
Deferred income taxes	65.0		(1.4)
Noncash share-based compensation	3.4		5.4
Asset impairment	2.0		—
Provision for NARM and Shoal Creek loss	33.7		—
Net gain on disposals	(7.1)		(17.7)
Noncash income from port and rail capacity assignment	(9.2)		—
Net loss on early debt extinguishment	8.8		25.8
Income from equity affiliates	(4.1)		(93.4)
Foreign currency option contracts	(0.6)		3.0
Changes in current assets and liabilities:
Accounts receivable	149.3		(179.9)
Inventories	(20.8)		(26.2)
Other current assets	43.4		(82.9)
Accounts payable and accrued expenses	(23.3)		(13.1)
Collateral arrangements	(116.9)		(28.2)
Asset retirement obligations	3.6		5.2
Workers’ compensation obligations	(0.7)		(1.6)
Postretirement benefit obligations	(30.4)		(32.2)
Pension obligations	0.7		(1.2)
Other, net	—		3.3
Net cash provided by continuing operations	745.2		12.1
Net cash used in discontinued operations	(5.5)		(2.7)
Net cash provided by operating activities	739.7		9.4

4

PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - (Continued)
	Six Months Ended June 30,
	2023		2022
	(Dollars in millions)
Cash Flows From Investing Activities
Additions to property, plant, equipment and mine development	(122.3)		(63.1)
Changes in accrued expenses related to capital expenditures	(5.4)		(9.7)
Proceeds from disposal of assets, net of receivables	12.0		23.4
Contributions to joint ventures	(370.8)		(276.0)
Distributions from joint ventures	365.8		280.8
Advances to related parties	(0.1)		(1.2)
Cash receipts from Middlemount Coal Pty Ltd and other related parties	1.7		143.9
Other, net	(0.9)		(3.6)
Net cash (used in) provided by investing activities	(120.0)		94.5
Cash Flows From Financing Activities
Proceeds from long-term debt	—		545.0
Repayments of long-term debt	(4.8)		(654.8)
Payment of debt issuance and other deferred financing costs	(0.3)		(20.7)
Proceeds from common stock issuances, net of costs	—		222.0
Common stock repurchases	(173.0)		—
Repurchase of employee common stock relinquished for tax withholding	(13.7)		(2.6)
Dividends paid	(10.8)		—
Distributions to noncontrolling interests	(22.8)		(13.8)
Net cash (used in) provided by financing activities	(225.4)		75.1
Net change in cash, cash equivalents and restricted cash	394.3		179.0
Cash, cash equivalents and restricted cash at beginning of period (1)	1,417.6		954.3
Cash, cash equivalents and restricted cash at end of period (2)	$	1,811.9	$	1,133.3
(1) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at beginning of period”:
Cash and cash equivalents	$	1,307.3
Restricted cash included in “Restricted cash and collateral”	110.3
Cash, cash equivalents and restricted cash at beginning of period	$	1,417.6
(2) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at end of period”:
Cash and cash equivalents	$	1,080.5
Restricted cash included in “Restricted cash and collateral”	731.4
Cash, cash equivalents and restricted cash at end of period	$	1,811.9

See accompanying notes to unaudited condensed consolidated financial statements.

5

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions, except per share data)
Common Stock
Balance, beginning of period	$	1.9	$	1.9	$	1.9	$	1.8
Common stock issuances, net of costs	—		—		—		0.1
Balance, end of period	1.9		1.9		1.9		1.9
Additional paid-in capital
Balance, beginning of period	3,977.6		3,969.5		3,975.9		3,745.6
Dividend equivalent units on dividends declared	0.1		—		0.1		—
Share-based compensation for equity-classified awards	1.7		3.4		3.4		5.4
Common stock issuances, net of costs	—		—		—		221.9
Balance, end of period	3,979.4		3,972.9		3,979.4		3,972.9
Treasury stock
Balance, beginning of period	(1,386.1)		(1,372.3)		(1,372.9)		(1,370.3)
Common stock repurchases	(173.0)		—		(173.0)		—
Unsettled common stock repurchases	(11.2)		—		(11.2)		—
Excise tax payable on common stock repurchases	(1.6)		—		(1.6)		—
Repurchase of employee common stock relinquished for tax withholding	(0.5)		(0.6)		(13.7)		(2.6)
Balance, end of period	(1,572.4)		(1,372.9)		(1,572.4)		(1,372.9)
Retained earnings (Accumulated deficit)
Balance, beginning of period	652.4		(1,032.7)		383.9		(913.2)
Net income attributable to common stockholders	179.2		409.5		447.7		290.0
Dividends declared ($0.075, $0.000, $0.075, and $0.000 per share, respectively)	(10.9)		—		(10.9)		—
Balance, end of period	820.7		(623.2)		820.7		(623.2)
Accumulated other comprehensive income
Balance, beginning of period	228.9		286.4		242.5		297.9
Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)		(13.5)		(26.8)		(26.9)
Foreign currency translation adjustment	(0.4)		(3.4)		(0.6)		(1.5)
Balance, end of period	215.1		269.5		215.1		269.5
Noncontrolling interests
Balance, beginning of period	55.0		44.1		63.5		59.0
Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Distributions to noncontrolling interests	—		—		(22.8)		(13.8)
Balance, end of period	78.6		45.2		78.6		45.2
Total stockholders’ equity	$	3,523.3	$	2,293.4	$	3,523.3	$	2,293.4

See accompanying notes to unaudited condensed consolidated financial statements.

6

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1)    Basis of Presentation

The 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, 2022. 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, 2022 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, 2023 are not necessarily indicative of the results that may be expected for future quarters or for the year ending December 31, 2023.

Although there are new accounting pronouncements issued by the Financial Accounting Standards Board that the Company will adopt, as applicable, the Company does not believe any of these accounting pronouncements will have a material impact on its unaudited condensed consolidated financial statements or disclosures.

(2)    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, 2022, for the Company’s policies regarding “Revenue” and “Accounts receivable, net.”

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, 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

7

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Three Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	39.8	$	—	$	229.9	$	222.8	$	—	$	492.5
Export	314.9		—		—		1.0		—		315.9
Total thermal	354.7		—		229.9		223.8		—		808.4
Metallurgical coal
Export	—		533.3		—		—		—		533.3
Total metallurgical	—		533.3		—		—		—		533.3
Other (2)	0.2		0.5		(0.2)		1.1		(21.4)		(19.8)
Revenue	$	354.9	$	533.8	$	229.7	$	224.9	$	(21.4)	$	1,321.9

	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

8

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Six Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	80.2	$	—	$	481.4	$	422.7	$	—	$	984.3
Export	525.4		—		—		1.0		—		526.4
Total thermal	605.6		—		481.4		423.7		—		1,510.7
Metallurgical coal
Export	—		851.3		—		—		—		851.3
Total metallurgical	—		851.3		—		—		—		851.3
Other (2)	0.5		3.8		(0.5)		4.3		(356.8)		(348.7)
Revenue	$	606.1	$	855.1	$	480.9	$	428.0	$	(356.8)	$	2,013.3

(1)    Corporate and Other includes the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Unrealized gains (losses) on derivative contracts related to forecasted sales	$	40.3	$	(24.5)	$	159.0	$	(325.5)
Realized losses on derivative contracts related to forecasted sales	(30.3)		(122.6)		(80.9)		(190.6)
Revenue from physical sale of coal (3)	23.3		122.0		107.8		143.3
Trading revenue	0.1		0.3		0.1		10.4
Other (2)	3.8		3.4		25.6		5.6
Total Corporate and Other	$	37.2	$	(21.4)	$	211.6	$	(356.8)

(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 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, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Trade receivables, net	$	278.5	$	416.3
Miscellaneous receivables, net	47.0		49.2
Accounts receivable, net	$	325.5	$	465.5

None of the above receivables included allowances for credit losses at June 30, 2023 or December 31, 2022. No charges for credit losses were recognized during the three and six months ended June 30, 2023 or 2022.

9

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(3)     Inventories

“Inventories, net” as of June 30, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Materials and supplies, net	$	152.0	$	130.8
Raw coal	94.2		98.3
Saleable coal	66.7		67.0
Inventories, net	$	312.9	$	296.1

Materials and supplies inventories, net presented above have been shown net of reserves of $8.5 million and $9.5 million as of June 30, 2023 and December 31, 2022.

(4) Equity Method Investments

The Company’s equity method investments include its joint venture interest 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 “Income from equity affiliates”:

					(Income) Loss from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2023		December 31, 2022		2023		2022		2023		2022
	(Dollars in millions)
Equity method investment related to Middlemount	$	33.1	$	27.1	$	(4.1)	$	(49.5)	$	(6.7)	$	(95.2)
Equity method investment related to R3	7.8		7.0		1.8		0.8		2.6		1.8
Total equity method investments	$	40.9	$	34.1	$	(2.3)	$	(48.7)	$	(4.1)	$	(93.4)

The Company received no cash payments from Middlemount during the six months ended June 30, 2023. Payments of $143.2 million were received from Middlemount during the six months ended June 30, 2022.

One of the Company’s Australian subsidiaries is party to an agreement to provide a revolving loan to Middlemount. The Company’s participation in the revolving loan will not, at any time, exceed its 50% equity interest of the revolving loan limit, which was $50 million Australian dollars at June 30, 2023. The revolving loan bears interest at 10% per annum and expires on December 31, 2023. There was no outstanding revolving loan at June 30, 2023 or December 31, 2022.

In March 2022, the Company entered into a joint venture with unrelated partners to form R3. R3 was formed 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 contributed $3.5 million and $2.5 million to R3 during the six months ended June 30, 2023 and 2022, respectively.

(5) 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, (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, (3) price risk and the variability of cash flows related to forecasted diesel fuel purchased for use in its operations and (4) interest rate risk on long-term debt. These risk management activities are actively monitored for compliance with the Company’s risk management policies.

10

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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. The Company had no diesel fuel or interest rate derivatives in place as of June 30, 2023.

Foreign Currency Option Contracts

The Company has historically utilized currency forwards and options to hedge currency risk associated with anticipated Australian dollar expenditures. As of June 30, 2023, the Company held average rate options with an aggregate notional amount of $486.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending March 31, 2024. 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 $0.75 over the nine-month period ending March 31, 2024. As of June 30, 2023, the Company also held purchased collars with an aggregate notional amount of $514.0 million Australian dollars related to anticipated Australian dollar expenditures during the nine-month period ending March 31, 2024. The purchased collars have a floor and ceiling of approximately $0.60 and $0.75, 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, 2023, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures, forwards and options. The Company classifies certain physical forward sales contracts as derivatives for which the normal purchase, normal sales exception does not apply.

During the three months ended June 30, 2023, the Company recorded a net unrealized mark-to-market gain of $40.3 million on financial coal derivative contracts, and no unrealized mark-to-market gains or losses on physical forward sales contracts. During the three months ended June 30, 2022, the Company recorded a net unrealized mark-to-market loss of $24.5 million on coal derivative contracts, which included approximately $40 million of unrealized mark-to-market losses on financial derivatives and approximately $15 million of unrealized mark-to-market gains on physical forward sales contracts.

During the six months ended June 30, 2023, the Company recorded a net unrealized mark-to-market gain of $159.0 million on financial coal derivative contracts, and no unrealized mark-to-market gains or losses on physical forward sales contracts. During the six months ended June 30, 2022, the Company recorded a net unrealized mark-to-market loss of $325.5 million on coal derivative contracts, which included approximately $306 million of unrealized mark-to-market losses on financial derivatives and approximately $20 million of unrealized mark-to-market losses on physical forward sales contracts.

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, 2023.

11

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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. The fair value of derivatives reflected in the accompanying condensed consolidated balance sheets are set forth in the table below.

	June 30, 2023				December 31, 2022
	Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative
	(Dollars in millions)
Foreign currency option contracts	$	0.9	$	—	$	3.0	$	—
Derivative contracts related to forecasted sales	30.4		(15.4)		100.6		(310.3)
Financial trading contracts	—		(15.0)		11.7		—
Total derivatives	31.3		(30.4)		115.3		(310.3)
Effect of counterparty netting	(30.4)		30.4		(100.6)		100.6
Variation margin (received) posted	—		—		(11.7)		209.7
Net derivatives and variation margin as classified in the balance sheets	$	0.9	$	—	$	3.0	$	—

The Company generally posts or receives variation margin cash with its clearing broker on the majority of its financial derivatives as market values of the financial derivatives fluctuate. As of June 30, 2023, the Company had no margin cash posted. As of December 31, 2022, the Company had posted $255.5 million aggregate margin cash, consisting of $198.0 million variation margin cash and $57.5 million initial margin.

The net amount of asset derivatives, net of variation margin, is included in “Other current assets” and the net amount of liability derivatives, net of variation margin, is included in “Accounts payable and accrued expenses” in the accompanying condensed consolidated balance sheets. The amounts of initial margin are not included with the derivatives presented in the tabular disclosures above and are included in “Other current assets” in the accompanying condensed consolidated balance sheets.

12

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, 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
		Three Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain 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	$	(7.5)	$	(1.2)	$	(6.3)
Derivative contracts related to forecasted sales	Revenue	(147.1)		(122.6)		(24.5)
Financial trading contracts	Revenue	0.3		0.9		(0.6)
Total		$	(154.3)	$	(122.9)	$	(31.4)
		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
		Six Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized (loss) gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(2.2)	$	(3.0)
Derivative contracts related to forecasted sales	Revenue	(516.1)		(190.6)		(325.5)
Financial trading contracts	Revenue	10.4		0.2		10.2
Total		$	(510.9)	$	(192.6)	$	(318.3)

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.

13

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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.

The following tables set forth the hierarchy of the Company’s net asset (liability) positions for which fair value is measured on a recurring basis. Variation margin cash associated with the derivative balances is excluded from this table.

	June 30, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	0.9	$	—	$	0.9
Derivative contracts related to forecasted sales	—		15.0		—		15.0
Financial trading contracts	—		(15.0)		—		(15.0)
Equity securities	—		—		0.3		0.3
Total net assets	$	—	$	0.9	$	0.3	$	1.2
	December 31, 2022
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	3.0	$	—	$	3.0
Derivative contracts related to forecasted sales	—		(209.7)		—		(209.7)
Financial trading contracts	—		11.7		—		11.7
Equity securities	—		—		2.5		2.5
Total net (liabilities) assets	$	—	$	(195.0)	$	2.5	$	(192.5)

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 currently 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, 2023 and December 31, 2022:

•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).

14

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Market risk associated with the Company’s fixed- and variable-rate long-term debt relates to the potential reduction in the fair value and negative impact to future earnings, respectively, 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, 2023		December 31, 2022
	(Dollars in millions)
Total debt at par value	$	343.5	$	343.6
Less: Unamortized debt issuance costs	(9.0)		(9.8)
Net carrying amount	$	334.5	$	333.8
Estimated fair value	$	454.8	$	560.0

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.

Significant increases or decreases in the inputs in isolation could result in a significantly higher or lower fair value measurement. The unobservable inputs do not have a direct interrelationship; therefore, a change in one unobservable input would not necessarily correspond with a change in another unobservable input.

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, and will mark the investment to market as a Level 1 asset prospectively.

The Company had no transfers between Levels 1, 2 and 3 during the three and six months ended June 30, 2023 and 2022. The Company’s policy is to value all transfers between levels using the beginning of period valuation.

(6) Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of June 30, 2023 and December 31, 2022 is set forth in the table below:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Land and coal interests	$	2,511.9	$	2,514.7
Buildings and improvements	628.8		594.2
Machinery and equipment	1,612.0		1,543.1
Less: Accumulated depreciation, depletion and amortization	(1,933.2)		(1,787.0)
Property, plant, equipment and mine development, net	$	2,819.5	$	2,865.0

(7)  Income Taxes

The Company's effective tax rate before remeasurement for the six months ended June 30, 2023 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 $74.2 million and $11.3 million for the three months ended June 30, 2023 and 2022, respectively, included a tax provision of $0.3 million and a tax benefit of $3.5 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax provisions of $192.2 million and $10.3 million for the six months ended June 30, 2023 and 2022, respectively, included a tax provision of $0.7 million and a tax benefit of $1.9 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.

15

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(8)     Long-term Debt 

The Company’s total indebtedness as of June 30, 2023 and December 31, 2022 consisted of the following:

Debt Instrument (defined below, as applicable)	June 30, 2023		December 31, 2022
	(Dollars in millions)
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0
Finance lease obligations	23.5		23.6
Less: Debt issuance costs	(9.0)		(9.8)
	334.5		333.8
Less: Current portion of long-term debt	13.0		13.2
Long-term debt	$	321.5	$	320.6

During 2022, the Company utilized various methods allowable or required under its then-existing debt agreements to retire all of its senior secured long-term debt, leaving only its unsecured 3.250% Convertible Senior Notes due 2028 (the 2028 Convertible Notes), which are further described below, and various finance lease obligations outstanding at December 31, 2022.

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.

The Company used the proceeds of the offering of the 2028 Convertible Notes and available cash to redeem $62.6 million of senior secured notes maturing in 2024 and $257.4 million of senior secured notes maturing in 2025, 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 and recognized a loss on early debt extinguishment of $23.0 million during the three months ended March 31, 2022.

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 bore interest from March 1, 2022 at a rate of 3.250% per year, payable semi-annually in arrears on March 1 and September 1 of each year, beginning on September 1, 2022.

The 2028 Convertible Notes’ indenture requires 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%. Under the applicable conversion rate formula, the $0.075 per share dividend declared on April 27, 2023 and paid on May 31, 2023 yielded a revised conversion rate of 50.5451 shares per $1,000 principal amount of 2028 Convertible Notes, which did not meet the 1% threshold to impact the existing conversion rate of 50.3816. The conversion rate may be impacted prospectively, based upon cumulative dividends paid.

During the first and second quarters of 2023, 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 2023, and will not be similarly convertible during the third quarter of 2023.

As of June 30, 2023, the if-converted value of the 2028 Convertible Notes exceeded the principal amount by $29.2 million.

16

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 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,
	2023		2022		2023		2022
	(Dollars in millions)
Indebtedness	$	5.3	$	24.0	$	11.7	$	49.9
Financial assurance instruments	8.0		13.6		20.0		27.1
Interest expense	$	13.3	$	37.6	$	31.7	$	77.0
Cash paid for interest	$	22.9	$	40.6	$	41.9	$	77.8
Non-cash interest expense	$	1.7	$	5.2	$	3.3	$	9.0

Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2023. The April 2023 termination of the Company’s credit agreement and related letter of credit facility, as described in Note 11. “Financial Instruments and Other Guarantees,” eliminated the related compliance requirements as of March 31, 2023 and prospectively.

(9) 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 (credit) included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Interest cost on projected benefit obligation	$	7.4	$	5.4	$	14.8	$	10.7
Expected return on plan assets	(6.6)		(6.0)		(13.2)		(11.9)
Net periodic pension cost (credit)	$	0.8	$	(0.6)	$	1.6	$	(1.2)

Annual contributions to the qualified plans 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 (generally 80%). As of June 30, 2023, the Company’s qualified plans were expected to be at or above the Pension Protection Act thresholds. The Company is not required to make any contributions to its qualified pension plans in 2023 based on minimum funding requirements and does not expect to make any discretionary contributions in 2023 at this time.

In March 2022, Peabody Investments Corp. (PIC), a wholly-owned subsidiary of PEC, entered into a commitment agreement relating to the Peabody Investments Corp. Retirement Plan (the Peabody Plan) with The Prudential Insurance Company of America (Prudential) and Fiduciary Counselors Inc., as independent fiduciary to the Peabody Plan. Under the commitment agreement, the Peabody Plan purchased a buy-in group annuity contract (GAC) from Prudential for approximately $500 million and Prudential would reimburse the Peabody Plan for benefit payments to be made to the Peabody Plan’s participants. The benefit obligation was not transferred to Prudential and the Peabody Plan continued to administer and pay the retirement benefits of Peabody Plan participants and was reimbursed by Prudential for the payment of all benefits covered by the GAC. The purchase of the GAC was funded directly by the Peabody Plan’s assets. There was no impact on the monthly retirement benefits paid to Peabody Plan participants and no material impact on contributions for the Peabody Plan in 2022 or 2023 as a result of this transaction.

17

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

In May 2022, the Board of Directors of PIC approved the termination of the Peabody Plan effective July 31, 2022. In June 2022, the Peabody Plan’s participants were notified of the Peabody Plan termination and PIC filed an application with the Internal Revenue Service to request a determination as to the qualified status under §401(a) of the Internal Revenue Code of 1986 with respect to the amendment and termination of the Peabody Plan. In May 2023, PIC received a favorable determination from the Internal Revenue Service as to the Peabody Plan’s qualified status with respect to its plan termination.

In February 2023, as part of the Peabody Plan termination process, PIC announced a program to offer a voluntary lump-sum pension payout to certain active and deferred participants of the Peabody Plan which would fully settle the Peabody Plan’s obligation to them. The program provided participants with a limited-time opportunity to elect to receive a lump-sum settlement of their pension benefit or begin to receive their benefit in the form of a monthly annuity in May 2023.

During the six months ended June 30, 2023, the Company settled $21.9 million of its pension obligations for active and deferred participants in the Peabody Plan with an equal amount paid from plan assets.

As part of the completion of the standard Employee Retirement Income Security Act plan termination process for the Peabody Plan, on July 31, 2023, the GAC with Prudential was converted from a buy-in group annuity contract to a buy-out group annuity contract, irrevocably transferring the remaining benefit obligation and administration to Prudential. The Peabody Plan no longer administers or pays the retirement benefits of Peabody Plan participants. No cash contributions are expected to be required to complete the termination process for the Peabody Plan.

Net periodic postretirement benefit credit included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Service cost for benefits earned	$	0.2	$	0.2	$	0.3	$	0.4
Interest cost on accumulated postretirement benefit obligation	2.5		1.8		5.0		3.5
Expected return on plan assets	(0.2)		(0.2)		(0.3)		(0.4)
Amortization of prior service credit	(13.4)		(13.5)		(26.8)		(26.9)
Net periodic postretirement benefit credit	$	(10.9)	$	(11.7)	$	(21.8)	$	(23.4)

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 2023 and plans to utilize a portion of VEBA assets to make certain benefit payments.

(10) 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.

18

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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, 2023 and 2022 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.

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,
	2023		2022		2023		2022
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	180.5		410.2		450.3		291.5
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	179.2	$	409.5	$	447.7	$	290.0
Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.5		2.5		6.1		3.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	184.0		412.7		456.4		295.0
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	182.7	$	412.0	$	453.8	$	293.5
EPS denominator:
Weighted average shares outstanding — basic	142.3		144.0		143.4		140.1
Dilutive impact of share-based compensation awards	0.6		1.8		0.7		1.5
Dilutive impact of 2028 Convertible Notes	16.1		16.1		16.1		10.9
Weighted average shares outstanding — diluted	159.0		161.9		160.2		152.5
Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.27	$	2.85	$	3.14	$	2.08
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.01)
Net income attributable to common stockholders	$	1.26	$	2.84	$	3.12	$	2.07
Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.16	$	2.55	$	2.85	$	1.93
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		—
Net income attributable to common stockholders	$	1.15	$	2.54	$	2.83	$	1.93

19

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(11) 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.

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

	June 30, 2023						December 31, 2022
	Reclamation Support		Other Support (1)		Total		Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	1,119.0	$	113.1	$	1,232.1	$	1,250.1	$	126.7	$	1,376.8
Letters of credit (2)	23.8		94.0		117.8		437.8		131.8		569.6
	1,142.8		207.1		1,349.9		1,687.9		258.5		1,946.4
Less: Letters of credit in support of surety bonds (3)	(23.8)		(5.9)		(29.7)		(431.7)		(37.2)		(468.9)
Obligations supported, net	$	1,119.0	$	201.2	$	1,320.2	$	1,256.2	$	221.3	$	1,477.5

(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 agreement, the Company was required to post collateral on a periodic basis through December 31, 2025. Prior to the April 2023 amendment, the Company had posted cumulative collateral of $557.8 million, primarily in the form of letters of credit.

Under the April 2023 amendment, the Company and 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 represented a negotiated increase from the uncapped cumulative collateral amount prior to the amendment and will vary prospectively as bonding levels increase or decrease. The amendment also removed restrictions on the payment of dividends and share repurchases, and extended the agreement through December 31, 2026. In order to maintain the new maximum collateral standstill, 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 $533.6 million at June 30, 2023. 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, which commenced for the second quarter of 2023. The Company granted second liens on $200.0 million of mining equipment under the original agreement, which remain in force under the April 2023 amendment.

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 credit agreement which, as amended, provided for $237.2 million of capacity for irrevocable standby letters of credit (LC Facility). All letters of credit that were outstanding under the LC Facility were cancelled upon its termination and, in certain cases, replaced by cash-collateralized letters of credit or letters of credit issued under the Company’s accounts receivable securitization program.

20

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 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.

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 secured overnight financing rate (SOFR). 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 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, 2023, the Company had no outstanding borrowings and $117.8 million of letters of credit outstanding under the Securitization Program, primarily in support of reclamation obligations. Availability under the Securitization Program, which is adjusted for certain ineligible receivables, was $34.8 million at June 30, 2023. The Company was not required to post cash collateral under the Securitization Program at June 30, 2023.

The Company incurred interest and fees associated with the Securitization Program of $0.8 million and $0.9 million during the three months ended June 30, 2023 and 2022, respectively, and $1.9 million and $1.8 million during the six months ended June 30, 2023 and 2022, respectively, which have been recorded as “Interest expense” in the accompanying unaudited condensed consolidated statements of operations.

Collateralized Letter of Credit Agreement

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, 2023, letters of credit of $168.2 million were outstanding under the agreement, which were collateralized by cash of $173.2 million.

21

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

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	558.2	$	—
Collateralized letters of credit funding (2)	173.2		110.3
	731.4		110.3
Other collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	194.0		33.6
LC Facility (3)	—		28.5
Deposit held on behalf of surety	—		15.0
	194.0		77.1
Restricted cash and collateral	$	925.4	$	187.4

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

(2)    Surety trust accounts and the funding for collateralized letters of credit 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.

(3)    Balance related to the Company’s mandatory repurchase of $30.0 million priority lien obligations under the LC Facility during 2022 at approximately 95%. The Company received approximately $30.0 million upon termination of the LC Facility on April 14, 2023.

(12) Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of June 30, 2023, purchase commitments for capital expenditures were $100.8 million, all of which is obligated within the next two years, with $94.1 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, 2022.

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.

22

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Litigation and Matters Relating to Continuing Operations

Metropolitan Mine Stormwater Discharge. Over the past few years, there has been significantly high rainfall in New South Wales, including unprecedented rain totals at the Metropolitan Mine site. While stormwater collected at the mine site is managed through two sedimentation dams, at times the heavy rainfall has presented challenges with managing the significant volumes of stormwater, as the surface water management infrastructure has not had sufficient capacity. As a result, on multiple occasions throughout 2021 and 2022 stormwater has been discharged from the mine site. Metropolitan Collieries Pty Ltd (MCPL), a wholly-owned subsidiary of PEC, removed accumulated material from the sedimentation dams to restore full site stormwater capacity by December 31, 2022 and has identified and is implementing additional controls for the management of sediment moving forward. Despite the measures undertaken by MCPL to manage and improve the situation, the Environment Protection Authority is currently undertaking an investigation in relation to the discharges of sediment laden water from the mine site and whether there are potential offenses against the environmental protection legislation arising from the stormwater discharges from the site. The Environmental Protection Authority has also completed a review of MCPL’s environmental protection license and has implemented some additional compliance conditions.

Puerto Rico Climate Change Lawsuit. On November 22, 2022, the Municipalities of Puerto Rico filed a class action complaint for damages against several major energy fuel producers, including Peabody Energy. This lawsuit represents the latest in a series of lawsuits that have been brought in both state and federal court around the United States, generally seeking to impose liability on the energy fuel producers for the effects allegedly caused by climate change. Many of these lawsuits have been brought on behalf of governmental entities (counties, cities, and towns) by plaintiff law firms on a contingent fee arrangement. The causes of action in the Puerto Rico lawsuit include public and private nuisance, liability for failure to warn, consumer fraud, antitrust and claims under the Racketeer Influenced and Corrupt Organizations Act. On April 21, 2023, the plaintiffs filed a Notice of Voluntary Dismissal dismissing all claims against the Company without prejudice.

Oregon Climate Change Lawsuit. On July 20, 2023, Peabody Energy was served with a summons issued on behalf of Multnomah County, Oregon. The complaint seeks 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, include a failure to warn, false or misleading advertisement and public nuisance. The Company will defend the claim and will continue to assert all applicable defenses available in regards to these claims.

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.

Claims, Litigation and Settlements Relating to Indemnities or Historical Operations

Patriot-Related Matters. Included in the Company’s discontinued operations are the previously divested legacy operations of Patriot Coal Corporation and certain of its wholly-owned subsidiaries (Patriot). In 2012, Patriot filed voluntary petitions for relief under Chapter 11 of Title 11 of the U.S. Code (the Bankruptcy Code). In 2013, the Company entered into a definitive settlement agreement (2013 Agreement) with Patriot and the United Mine Workers of America, on behalf of itself, its represented Patriot employees and its represented Patriot retirees, to resolve all then-disputed issues related to Patriot’s bankruptcy. In May 2015, Patriot again filed voluntary petitions for relief under the Bankruptcy Code and subsequently initiated a process to sell substantially all of its assets to qualified bidders. On October 9, 2015, Patriot’s bankruptcy court entered an order confirming Patriot’s plan of reorganization, which provided, among other things, for the sale of substantially all of Patriot’s assets to two different buyers.

Patriot had federal and state black lung occupational disease liabilities related to workers employed in periods prior to Patriot’s spin-off from the Company in 2007. Upon spin-off, Patriot indemnified the Company against any claim relating to these liabilities, which amounted to approximately $150 million at that time. The indemnification included any claim made by the U.S. Department of Labor (DOL) against the Company with respect to these obligations as a potentially liable operator under the Federal Coal Mine Health and Safety Act of 1969. The 2013 Agreement included Patriot’s affirmance of indemnities provided in the spin-off agreements, including the indemnity relating to such black lung liabilities; however, Patriot rejected this indemnity in its May 2015 bankruptcy.

23

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

By statute, the Company had secondary liability for the black lung liabilities related to Patriot’s workers employed by former subsidiaries of the Company. The Company’s accounting for the black lung liabilities related to Patriot is based on an interpretation of applicable statutes. Management believes that inconsistencies exist among the applicable statutes, regulations promulgated under those statutes and the DOL’s interpretative guidance. The Company has sought clarification from the DOL regarding these inconsistencies and has challenged the DOL’s position in individual black lung claims. The amount of these liabilities could be reduced in the future. Whether the Company will ultimately be required to fund certain of those obligations in the future as a result of Patriot’s May 2015 bankruptcy remains uncertain. The amount of the liability, which was determined on an actuarial basis based on the best information available to the Company, was $80.0 million and $82.3 million at June 30, 2023 and December 31, 2022, respectively. The liability, which is classified as discontinued operations, is included in the Company’s condensed consolidated balance sheets within “Accounts payable and accrued expenses” and “Other noncurrent liabilities.” While the Company has recorded a liability, it intends to review each claim on a case-by-case basis and contest liability estimates as appropriate. The amount of the Company’s recorded liability reflects only Patriot workers employed by former subsidiaries of the Company that are presently retired, disabled or otherwise not actively employed. The Company cannot reliably estimate the potential liabilities for Patriot’s workers employed by former subsidiaries of the Company that are presently active in the workforce because of the potential for such workers to continue to work for another coal operator that is a going concern.

(13) 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 chief operating decision maker, 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,
	2023		2022		2023		2022
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	399.5	$	354.9	$	746.0	$	606.1
Seaborne Metallurgical	372.5		533.8		660.9		855.1
Powder River Basin	259.7		229.7		565.0		480.9
Other U.S. Thermal	199.9		224.9		449.3		428.0
Corporate and Other	37.2		(21.4)		211.6		(356.8)
Total	$	1,268.8	$	1,321.9	$	2,632.8	$	2,013.3
Adjusted EBITDA:
Seaborne Thermal	$	197.5	$	176.8	$	361.5	$	267.3
Seaborne Metallurgical	102.5		299.7		193.3		480.7
Powder River Basin	26.2		(2.0)		62.0		5.6
Other U.S. Thermal	51.9		61.9		116.1		111.9
Corporate and Other	(19.9)		41.4		15.9		39.8
Total	$	358.2	$	577.8	$	748.8	$	905.3

24

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,
	2023		2022		2023		2022
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Depreciation, depletion and amortization	80.6		73.8		156.9		146.7
Asset retirement obligation expenses	15.5		12.7		30.9		27.7
Restructuring charges	2.0		0.2		2.1		1.8
Asset impairment	—		—		2.0		—
Provision for NARM and Shoal Creek loss	33.7		—		33.7		—
Changes in amortization of basis difference related to equity affiliates	(0.4)		(0.6)		(0.7)		(1.2)
Interest expense	13.3		37.6		31.7		77.0
Net loss on early debt extinguishment	2.0		2.3		8.8		25.8
Interest income	(23.1)		(0.9)		(36.2)		(1.4)
Unrealized (gains) losses on derivative contracts related to forecasted sales	(40.3)		24.5		(159.0)		325.5
Unrealized (gains) losses on foreign currency option contracts	(2.8)		6.3		(0.6)		3.0
Take-or-pay contract-based intangible recognition	(0.6)		(0.7)		(1.2)		(1.4)
Income tax provision	74.2		11.3		192.2		10.3
Adjusted EBITDA	$	358.2	$	577.8	$	748.8	$	905.3

(14) Other Events

Share Repurchases

During the three months ended June 30, 2023, the Company repurchased approximately 8.9 million shares of its common stock for $184.2 million, including commission fees. Of this amount, $11.2 million related to repurchases which settled subsequent to June 30, 2023. The Company recognized excise taxes of $1.6 million related to the repurchases, which were unpaid at June 30, 2023. The Company includes commission fees and excise taxes, as incurred, with the cost of treasury stock. Subsequent to June 30, 2023, the Company repurchased an additional 3.1 million shares for $67.0 million.

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. The provision includes $4.0 million for materials and supplies inventories and $1.0 million for buildings and equipment. This provision represents the best estimate of potential loss based on the assessments made to date. The Company continues to assess the loss and anticipates that incremental repair costs will be recorded in future periods.

Shoal Creek Incident

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. Development coal production has been resumed in a new 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. The provision includes $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.

25

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 North Goonyella 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 is 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 and had a discounted receivable of $9.3 million included in “Accounts receivable, net” as of June 30, 2023.

26

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, Item 1A. “Risk Factors” of Part II of its Quarterly Report on Form 10-Q for the quarter ended March 31, 2023 filed with the SEC on May 4, 2023 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, 2022 filed with the SEC on February 24, 2023. 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 management as the primary metric to measure each of its 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 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.

27

Overview

Peabody is a leading producer of metallurgical and thermal coal. In 2022, the Company produced and sold 122.9 million and 123.7 million tons of coal, respectively, from continuing operations. At June 30, 2023, 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 during 2022, 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 13. “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, 2023 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, 2023 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, 2023 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, 2023		July 28, 2023
Premium HCC (1)	$	300.00	$	222.00	$	242.84	$	233.00	$	237.00
Premium PCI coal (1)	262.50		187.00		208.73		189.00		163.00
Newcastle index thermal coal (1)	199.58		120.23		158.30		137.94		140.33
API 5 index thermal coal (1)	120.24		84.17		102.33		85.93		86.66
PRB 8,800 Btu/Lb coal (2)	14.60		14.30		14.44		14.30		14.30
Illinois Basin 11,500 Btu/Lb coal (2)	73.00		51.00		59.42		51.00		50.00

(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 have been impacted by the ongoing Russian-Ukrainian conflict. Furthermore, inflationary pressures and supply chain constraints have contributed to rising costs and may continue to impact future periods. As future developments related to the Russian-Ukrainian conflict and rising inflation are unknown, the global coal industry data for the six months ended June 30, 2023 presented herein may not be indicative of their ultimate impacts.

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Within the seaborne metallurgical coal market, the six months ended June 30, 2023 were characterized by ongoing volatility as global macroeconomic turbulence combined with seasonal demand and supply fluctuations. The steel sector showed positive signs in early 2023 with several steelmakers announcing blast furnace capacity restarts; however ongoing economic uncertainty and multi-year high steel exports from China have dampened the revival and impacted metallurgical coal demand in key markets. Russian coal remains banned in the European Union, Japan and elsewhere, disrupting natural trade flows and resulting in low priced Russian products being made available to countries, such as China and India, which can continue procurement. Combined with abundant domestic and Mongolian supply, this is further enabling China to readily compete in the international steel market. Further economic stimulus in China, India and elsewhere, combined with seasonal demand growth is fueling positive sentiment in the market outlook to the end of the year.

Within the seaborne thermal coal market, global thermal coal prices have remained volatile during the quarter ended June 30, 2023 with prices declining from the first quarter. China has ended its unofficial ban of Australian coal imports, providing additional demand for Australian thermal coal through the six months ended June 30, 2023. In China, domestic coal production and renewable generation have been strong through the six months ended June 30, 2023; however, import demand has been higher year-over-year, as overall coal demand has been strong. 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 lower global natural gas prices.

In the United States, overall electricity demand decreased nearly 4% year-over-year, negatively impacted by weather. Through the six months ended June 30, 2023, electricity generation from thermal coal has declined year-over-year due to low natural gas prices and nearly level year-over-year renewable generation despite lower overall electricity demand. Coal’s share of electricity generation has declined to approximately 15% for the six months ended June 30, 2023, while wind and solar’s combined generation share has increased to 17% and the share of natural gas generation has increased to 40%. Coal inventories have increased during the six months ended June 30, 2023, with an increase of approximately 50%. During the six months ended June 30, 2023, utility consumption of PRB coal declined approximately 25% compared to the prior year period.

Surety Agreement Amendment and Shareholder Return Program

On April 14, 2023, the Company amended its existing agreement with the providers of its surety bond portfolio, dated November 6, 2020. Under the agreement, the Company was required to post collateral on a periodic basis. Pursuant to the amendment, the Company and its surety bond providers agreed to (i) establish a combined maximum collateral cap, (ii) remove the restrictions on shareholder returns contained in the original agreement, subject to a minimum liquidity threshold, and (iii) extend the expiration date of the existing agreement from December 31, 2025 to December 31, 2026. Peabody also terminated the letter of credit facility which was previously used primarily for surety collateral, further reducing interest costs and increasing financial flexibility.

On April 17, 2023, the Company announced that its Board of Directors (Board) approved a new shareholder return framework which includes a share repurchase plan, a fixed quarterly cash dividend and a variable quarterly cash dividend component. The Board also approved a new share repurchase program authorizing repurchases up to $1.0 billion of the Company’s common stock.

Refer to the “Liquidity and Capital Resources” section contained within this Item 2 and Part II, Item 2. “Unregistered Sales of Equity Securities and Use of Proceeds” for a further discussion of the surety agreement amendment.

Other

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. Development coal production has been resumed in a new 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. The provision includes $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.

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On June 23, 2023, the Company’s North Antelope Rochelle Mine (NARM) 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. The provision includes $4.0 million for materials and supplies inventories and $1.0 million for buildings and equipment. This provision represents the best estimate of potential loss based on the assessments made to date. The Company continues to assess the loss and anticipates that incremental repair costs will be recorded in future periods.

Results of Operations

Three and Six Months Ended June 30, 2023 Compared to the Three and Six Months Ended June 30, 2022

Summary

The decrease in income from continuing operations, net of income taxes for the three months ended June 30, 2023 compared to the same period in the prior year ($207.2 million), was driven by a higher tax provision ($62.9 million); lower revenue ($53.1 million) primarily due to a 42% decrease in metallurgical pricing; decreased results from equity affiliates ($46.4 million); higher operating costs and expenses ($36.4 million); and a provision of $33.7 million related to the losses at NARM and Shoal Creek. This unfavorable variance was partially offset by lower net interest expense ($46.8 million).

The increase in income from continuing operations, net of income taxes for the six months ended June 30, 2023 compared to the same period in the prior year ($196.7 million), was primarily driven by higher revenue ($619.5 million) due to net unrealized mark-to-market gains on derivative contracts related to forecasted coal sales and lower net interest expense ($97.1 million). This favorable variance was partially offset by higher operating costs and expenses ($184.0 million), which reflect increased sales price sensitive costs and inflationary pressures for materials, services, repairs and labor; a higher income tax provision ($181.9 million); decreased results from equity affiliates ($89.3 million); and a provision of $33.7 million related to the losses at NARM and Shoal Creek.

Adjusted EBITDA for the three and six months ended June 30, 2023 reflected year-over-year decreases of $219.6 million and $156.5 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,		(Decrease) Increase to Volumes
	2023	2022	Tons	%		2023	2022	Tons	%
	(Tons in millions)					(Tons in millions)
Seaborne Thermal	4.0	4.0	—	—	%	7.6	7.8	(0.2)	(3)	%
Seaborne Metallurgical	2.0	1.6	0.4	25	%	3.3	2.8	0.5	18	%
Powder River Basin	18.9	18.5	0.4	2	%	40.9	39.1	1.8	5	%
Other U.S. Thermal	3.8	4.4	(0.6)	(14)	%	8.3	8.6	(0.3)	(3)	%
Total tons sold from operating segments	28.7	28.5	0.2	1	%	60.1	58.3	1.8	3	%
Corporate and Other	0.2	0.1	0.1	100	%	0.3	0.2	0.1	50	%
Total tons sold	28.9	28.6	0.3	1	%	60.4	58.5	1.9	3	%

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Supplemental Financial Data

The following table presents supplemental financial data by operating segment:

	Three Months Ended June 30,				Increase (Decrease)				Six Months Ended June 30,				Increase (Decrease)
	2023		2022		$		%		2023		2022		$		%
Revenue per Ton (1)
Seaborne Thermal	$	100.59	$	87.37	$	13.22	15	%	$	98.81	$	77.52	$	21.29	27	%
Seaborne Metallurgical	190.13		330.56		(140.43)		(42)	%	202.33		299.82		(97.49)		(33)	%
Powder River Basin	13.71		12.44		1.27		10	%	13.80		12.30		1.50		12	%
Other U.S. Thermal	53.63		51.40		2.23		4	%	54.23		49.96		4.27		9	%
Costs per Ton (1)(2)
Seaborne Thermal	$	50.88	$	43.85	$	7.03	16	%	$	50.94	$	43.33	$	7.61	18	%
Seaborne Metallurgical	137.78		144.91		(7.13)		(5)	%	143.14		131.26		11.88		9	%
Powder River Basin	12.33		12.55		(0.22)		(2)	%	12.28		12.16		0.12		1	%
Other U.S. Thermal	39.71		37.25		2.46		7	%	40.22		36.90		3.32		9	%
Adjusted EBITDA Margin per Ton (1)(2)
Seaborne Thermal	$	49.71	$	43.52	$	6.19	14	%	$	47.87	$	34.19	$	13.68	40	%
Seaborne Metallurgical	52.35		185.65		(133.30)		(72)	%	59.19		168.56		(109.37)		(65)	%
Powder River Basin	1.38		(0.11)		1.49		1,355	%	1.52		0.14		1.38		986	%
Other U.S. Thermal	13.92		14.15		(0.23)		(2)	%	14.01		13.06		0.95		7	%

(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; and certain other costs related to post-mining activities.

Revenue

The following table presents revenue by reporting segment:

	Three Months Ended June 30,				Increase (Decrease) to Revenue				Six Months Ended June 30,				Increase (Decrease) to Revenue
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	399.5	$	354.9	$	44.6	13	%	$	746.0	$	606.1	$	139.9	23	%
Seaborne Metallurgical	372.5		533.8		(161.3)		(30)	%	660.9		855.1		(194.2)		(23)	%
Powder River Basin	259.7		229.7		30.0		13	%	565.0		480.9		84.1		17	%
Other U.S. Thermal	199.9		224.9		(25.0)		(11)	%	449.3		428.0		21.3		5	%
Corporate and Other	37.2		(21.4)		58.6		274	%	211.6		(356.8)		568.4		159	%
Revenue	$	1,268.8	$	1,321.9	$	(53.1)	(4)	%	$	2,632.8	$	2,013.3	$	619.5	31	%

Seaborne Thermal. Segment revenue increased during the three and six months ended June 30, 2023 compared to the same periods in the prior year due to favorable mix variances ($35.5 million and $66.3 million, respectively) which offset unfavorable volumes and favorable realized prices ($9.1 million and $73.6 million, respectively).

Seaborne Metallurgical. Segment revenue decreased during the three and six months ended June 30, 2023 compared to the same periods in the prior year due to unfavorable realized prices ($204.0 million and $226.8 million, respectively) and unfavorable volumes from the Shoal Creek Mine resulting from the fire in the first quarter of 2023 ($121.3 million and $124.6 million, respectively), offset by favorable volumes from the Australian operations ($164.0 million and $157.2 million, respectively).

Powder River Basin. Segment revenue increased during the three and six months ended June 30, 2023 compared to the same periods in the prior year due to favorable realized prices ($25.9 million and $65.2 million, respectively) and favorable volumes ($4.1 million and $18.9 million, respectively) resulting from improved rail performance.

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Other U.S. Thermal. Segment revenue decreased during the three months ended June 30, 2023 compared to the same period in the prior year due to unfavorable volumes ($41.4 million) resulting from decreased demand, offset by favorable realized prices ($16.4 million). Segment revenue increased during the six months ended June 30, 2023 compared to the same period in the prior year due to favorable realized prices ($43.5 million), offset by unfavorable volumes ($22.2 million) resulting from decreased demand.

Corporate and Other. Segment revenue increased during the three months ended June 30, 2023 compared to the same period in the prior year due to net unrealized mark-to-market gains on derivative contracts related to forecasted coal sales in the current year compared to net unrealized mark-to-market losses in the prior year ($64.8 million), partially offset by lower results from trading activities ($6.6 million). Segment revenue increased during the six months ended June 30, 2023 compared to the same period in the prior year due to net unrealized mark-to-market gains on derivative contracts related to forecasted coal sales in the current year compared to net unrealized mark-to-market losses in the prior year ($484.5 million); higher results from trading activities ($63.9 million) primarily due to lower net realized losses on derivative contracts related to forecasted coal sales; and revenue related to the Company’s assignment of rights to its excess port and rail capacity ($19.2 million) as discussed in Note 14. “Other Events” to the accompanying unaudited condensed consolidated financial statements.

Adjusted EBITDA

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

	Three Months Ended June 30,				Increase (Decrease) to Segment Adjusted EBITDA				Six Months Ended June 30,				Increase (Decrease) to Segment Adjusted EBITDA
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	197.5	$	176.8	$	20.7	12	%	$	361.5	$	267.3	$	94.2	35	%
Seaborne Metallurgical	102.5		299.7		(197.2)		(66)	%	193.3		480.7		(287.4)		(60)	%
Powder River Basin	26.2		(2.0)		28.2		1,410	%	62.0		5.6		56.4		1,007	%
Other U.S. Thermal	51.9		61.9		(10.0)		(16)	%	116.1		111.9		4.2		4	%
Corporate and Other	(19.9)		41.4		(61.3)		(148)	%	15.9		39.8		(23.9)		(60)	%
Adjusted EBITDA (1)	$	358.2	$	577.8	$	(219.6)	(38)	%	$	748.8	$	905.3	$	(156.5)	(17)	%

(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 increased during the three and six months ended June 30, 2023 compared to the same periods in the prior year as a result of favorable mix variances ($23.8 million and $53.6 million, respectively) and higher realized prices net of sales sensitive costs ($8.6 million and $68.8 million, respectively), partially offset by unfavorable operational costs ($11.5 million and $19.8 million, respectively) resulting from higher costs for repairs, maintenance and labor.

Seaborne Metallurgical. Segment Adjusted EBITDA decreased during the three and six months ended June 30, 2023 compared to the same periods in the prior year due to lower realized prices net of sales sensitive costs ($199.8 million and $229.7 million, respectively) and unfavorable operational costs ($87.6 million and $137.4 million, respectively) resulting from the fire at the Shoal Creek Mine in the first quarter of 2023 and increased repair and maintenance spend at the Australian metallurgical operations, partially offset by favorable volumes ($92.0 million and $87.8 million, respectively).

Powder River Basin. Segment Adjusted EBITDA increased during the three and six months ended June 30, 2023 compared to the same periods in the prior year due to favorable commodity pricing ($13.3 million and $11.3 million, respectively); higher realized prices net of sales sensitive costs ($13.2 million and $34.8 million, respectively); and decreased overburden removal costs (six months, $14.4 million). The increases were partially offset by higher costs for materials, services, repairs and labor ($0.5 million and $10.0 million, respectively) due in part to timing, increased repairs for an aging equipment fleet and inflationary pressures on materials and services.

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Other U.S. Thermal. Segment Adjusted EBITDA decreased during the three months ended June 30, 2023 compared to the same period in the prior year due to higher costs for materials, services, repairs and labor ($17.0 million) due in part to timing, increased repairs for an aging equipment fleet and inflationary pressures on materials and services and unfavorable volumes ($16.1 million). These decreases were offset by higher realized prices net of sales sensitive costs ($14.3 million) and favorable commodity pricing ($10.5 million). Segment Adjusted EBITDA increased during the six months ended June 30, 2023 compared to the same period in the prior year due to higher realized prices net of sales sensitive costs ($37.1 million) and favorable commodity pricing ($10.6 million), offset by higher costs for materials, services, repairs and labor ($32.6 million) due in part to increased equipment repairs and headcount and inflationary pressures on materials and services and unfavorable volumes ($7.1 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
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Middlemount (1)	$	3.7	$	48.9	$	(45.2)	(92)	%	$	6.0	$	94.0	$	(88.0)	(94)	%
Resource management activities (2)	6.0		13.8		(7.8)		(57)	%	8.3		17.3		(9.0)		(52)	%
Selling and administrative expenses	(21.7)		(21.8)		0.1		—	%	(44.5)		(44.9)		0.4		1	%
Other items, net (3)	(7.9)		0.5		(8.4)		(1,680)	%	46.1		(26.6)		72.7		273	%
Corporate and Other Adjusted EBITDA	$	(19.9)	$	41.4	$	(61.3)	(148)	%	$	15.9	$	39.8	$	(23.9)	(60)	%

(1)Middlemount’s results are before the impact of related changes in amortization of basis difference. Middlemount’s standalone results included (on a 50% attributable basis) aggregate amounts of depreciation, depletion and amortization, asset retirement obligation expenses, net interest expense and income taxes of $3.3 million and $23.3 million during the three months ended June 30, 2023 and 2022, respectively, and $5.9 million and $43.5 million during the six months ended June 30, 2023 and 2022, respectively.

(2)Includes gains (losses) on certain surplus coal reserve, 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 North Goonyella Mine and expenses related to the Company’s other commercial activities.

Corporate and Other Adjusted EBITDA decreased during the three months ended June 30, 2023 compared to the same period in the prior year primarily due to unfavorable variances in Middlemount’s results driven by a 40% decrease in sales pricing and lower sales volumes.

Corporate and Other Adjusted EBITDA decreased during the six months ended June 30, 2023 compared to the same period in the prior year due to unfavorable variances in Middlemount’s results driven by a 29% decrease in sales pricing and lower sales volumes, offset by favorable trading results ($68.6 million) and revenue related to the Company’s assignment of rights to its excess port and rail capacity ($19.2 million) as discussed in Note 14. “Other Events” to the accompanying unaudited condensed consolidated financial statements.

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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
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Adjusted EBITDA (1)	$	358.2	$	577.8	$	(219.6)	(38)	%	$	748.8	$	905.3	$	(156.5)	(17)	%
Depreciation, depletion and amortization	(80.6)		(73.8)		(6.8)		(9)	%	(156.9)		(146.7)		(10.2)		(7)	%
Asset retirement obligation expenses	(15.5)		(12.7)		(2.8)		(22)	%	(30.9)		(27.7)		(3.2)		(12)	%
Restructuring charges	(2.0)		(0.2)		(1.8)		(900)	%	(2.1)		(1.8)		(0.3)		(17)	%
Asset impairment	—		—		—		n.m.		(2.0)		—		(2.0)		n.m.
Provision for NARM and Shoal Creek loss	(33.7)		—		(33.7)		n.m.		(33.7)		—		(33.7)		n.m.
Changes in amortization of basis difference related to equity affiliates	0.4		0.6		(0.2)		(33)	%	0.7		1.2		(0.5)		(42)	%
Interest expense	(13.3)		(37.6)		24.3		65	%	(31.7)		(77.0)		45.3		59	%
Net loss on early debt extinguishment	(2.0)		(2.3)		0.3		13	%	(8.8)		(25.8)		17.0		66	%
Interest income	23.1		0.9		22.2		2,467	%	36.2		1.4		34.8		2,486	%
Unrealized gains (losses) on derivative contracts related to forecasted sales	40.3		(24.5)		64.8		264	%	159.0		(325.5)		484.5		149	%
Unrealized gains (losses) on foreign currency option contracts	2.8		(6.3)		9.1		144	%	0.6		(3.0)		3.6		120	%
Take-or-pay contract-based intangible recognition	0.6		0.7		(0.1)		(14)	%	1.2		1.4		(0.2)		(14)	%
Income tax provision	(74.2)		(11.3)		(62.9)		(557)	%	(192.2)		(10.3)		(181.9)		(1,766)	%
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	(207.2)	(50)	%	$	488.2	$	291.5	$	196.7	67	%

(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.

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
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal	$	(27.6)	$	(26.2)	$	(1.4)	(5)	%	$	(51.4)	$	(50.2)	$	(1.2)	(2)	%
Seaborne Metallurgical	(22.9)		(22.0)		(0.9)		(4)	%	(44.0)		(41.9)		(2.1)		(5)	%
Powder River Basin	(10.6)		(9.3)		(1.3)		(14)	%	(22.3)		(19.8)		(2.5)		(13)	%
Other U.S. Thermal	(17.1)		(13.7)		(3.4)		(25)	%	(34.8)		(29.4)		(5.4)		(18)	%
Corporate and Other	(2.4)		(2.6)		0.2		8	%	(4.4)		(5.4)		1.0		19	%
Total	$	(80.6)	$	(73.8)	$	(6.8)	(9)	%	$	(156.9)	$	(146.7)	$	(10.2)	(7)	%

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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,
	2023		2022		2023		2022
Seaborne Thermal	$	2.09	$	2.46	$	2.13	$	2.47
Seaborne Metallurgical	1.82		3.42		1.96		2.85
Powder River Basin	0.30		0.32		0.30		0.32
Other U.S. Thermal	1.33		1.24		1.26		1.21

The decrease in the weighted-average depletion rate per ton for the Seaborne Thermal segment during the three and six months ended June 30, 2023 compared to the same periods in the prior year reflects the impact of volume and mix variances across the segment. The decrease in the weighted-average depletion rate per ton for the Seaborne Metallurgical segment during the three and six months ended June 30, 2023 compared to the same periods in the prior year reflects the impact of the fire at the Shoal Creek Mine.

Provision for NARM and Shoal Creek Loss. A provision of $33.7 million million was recorded during the three and six months ended June 30, 2023 for losses related to the events at NARM and the Shoal Creek Mine, as discussed in Note 14. “Other Events” in the accompanying unaudited condensed consolidated financial statements. The current period provision represents the best estimate of potential loss associated with these events based on assessments made to date.

Interest Expense. The decrease in interest expense during the three and six months ended June 30, 2023 primarily reflects the impacts of debt retirements completed by the Company during 2022 as further described in Note 8. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements and Note 10. “Long-term Debt” to the Annual Report on Form 10-K for the year ended December 31, 2022.

Net Loss on Early Debt Extinguishment. The losses recognized during the three and six months ended June 30, 2023 were primarily related to the Company’s terminated letter of credit facility as further discussed in Note 11. “Financial Instruments and Other Guarantees” to the accompanying unaudited condensed consolidated financial statements. The losses recognized during the prior year periods were primarily related to the redemption of existing notes during the periods as further described in Note 8. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements and Note 10. “Long-term Debt” to the Annual Report on Form 10-K for the year ended December 31, 2022.

Interest Income. The increase in interest income during the three and six months ended June 30, 2023 was primarily due to higher cash balances, including restricted cash balances on which the Company earns interest, and higher interest rates in the current year. Based upon projected cash balances and interest rates, the Company anticipates significantly higher interest income throughout 2023 as compared to the prior year.

Unrealized Gains (Losses) on Derivative Contracts Related to Forecasted Sales. Unrealized gains (losses) primarily relate to mark-to-market activity on derivative contracts related to forecasted coal sales. For additional information, refer to Note 5. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

Unrealized Gains (Losses) on Foreign Currency Option Contracts. Unrealized gains (losses) primarily relate to mark-to-market activity on foreign currency option contracts. For additional information, refer to Note 5. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

Income Tax Provision. The increase in the income tax provision during the three and six months ended June 30, 2023 compared to the same periods in the prior year was primarily due to an increase in pretax income and the release of valuation allowance related to Australian net operating losses during the fourth quarter of 2022. Refer to Note 7. “Income Taxes” to the accompanying unaudited condensed consolidated financial statements for additional information.

35

Net Income Attributable to Common Stockholders

The following table presents net income attributable to common stockholders:

	Three Months Ended June 30,				(Decrease) Increase to Income				Six Months Ended June 30,				Increase (Decrease) to Income
	2023		2022		$		%		2023		2022		$		%
	(Dollars in millions)								(Dollars in millions)
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	(207.2)	(50)	%	$	488.2	$	291.5	$	196.7	67	%
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(0.6)		(86)	%	(2.6)		(1.5)		(1.1)		(73)	%
Net income	202.8		410.6		(207.8)		(51)	%	485.6		290.0		195.6		67	%
Less: Net income attributable to noncontrolling interests	23.6		1.1		22.5		2,045	%	37.9		—		37.9		n.m.
Net income attributable to common stockholders	$	179.2	$	409.5	$	(230.3)	(56)	%	$	447.7	$	290.0	$	157.7	54	%

Net Income Attributable to Noncontrolling Interests. The increase in the results attributable to noncontrolling interests during the three and six months ended June 30, 2023 compared to the same periods in the prior year was primarily due to stronger 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,				Decrease to EPS				Six Months Ended June 30,				Increase (Decrease) to EPS
	2023		2022		$		%		2023		2022		$		%
Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.16	$	2.55	$	(1.39)	(55)	%	$	2.85	$	1.93	$	0.92	48	%
Loss from discontinued operations	(0.01)		(0.01)		—		—	%	(0.02)		—		(0.02)		n.m.
Net income attributable to common stockholders	$	1.15	$	2.54	$	(1.39)	(55)	%	$	2.83	$	1.93	$	0.90	47	%

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 159.0 million and 161.9 million for the three months ended June 30, 2023 and 2022, respectively, and 160.2 million and 152.5 million for the six months ended June 30, 2023 and 2022, 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,
	2023		2022		2023		2022
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Depreciation, depletion and amortization	80.6		73.8		156.9		146.7
Asset retirement obligation expenses	15.5		12.7		30.9		27.7
Restructuring charges	2.0		0.2		2.1		1.8
Asset impairment	—		—		2.0		—
Provision for NARM and Shoal Creek loss	33.7		—		33.7		—
Changes in amortization of basis difference related to equity affiliates	(0.4)		(0.6)		(0.7)		(1.2)
Interest expense	13.3		37.6		31.7		77.0
Net loss on early debt extinguishment	2.0		2.3		8.8		25.8
Interest income	(23.1)		(0.9)		(36.2)		(1.4)
Unrealized (gains) losses on derivative contracts related to forecasted sales	(40.3)		24.5		(159.0)		325.5
Unrealized (gains) losses on foreign currency option contracts	(2.8)		6.3		(0.6)		3.0
Take-or-pay contract-based intangible recognition	(0.6)		(0.7)		(1.2)		(1.4)
Income tax provision	74.2		11.3		192.2		10.3
Total Adjusted EBITDA	$	358.2	$	577.8	$	748.8	$	905.3

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,
	2023		2022		2023		2022
	(Dollars in millions)
Operating costs and expenses	$	862.0	$	825.6	$	1,708.6	$	1,524.6
Unrealized gains (losses) on foreign currency option contracts	2.8		(6.3)		0.6		(3.0)
Take-or-pay contract-based intangible recognition	0.6		0.7		1.2		1.4
Net periodic benefit credit, excluding service cost	(9.7)		(12.3)		(19.4)		(24.5)
Total Reporting Segment Costs	$	855.7	$	807.7	$	1,691.0	$	1,498.5

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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,
	2023		2022		2023		2022
	(Dollars in millions)
Seaborne Thermal	$	202.0	$	178.1	$	384.5	$	338.8
Seaborne Metallurgical	270.0		234.1		467.6		374.4
Powder River Basin	233.5		231.7		503.0		475.3
Other U.S. Thermal	148.0		163.0		333.2		316.1
Corporate and Other	2.2		0.8		2.7		(6.1)
Total Reporting Segment Costs	$	855.7	$	807.7	$	1,691.0	$	1,498.5

Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenue by segment and Adjusted EBITDA by segment, 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, 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

	Three Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	4.0		1.6		18.5		4.4
Revenue	$	354.9	$	533.8	$	229.7	$	224.9
Total Reporting Segment Costs	178.1		234.1		231.7		163.0
Adjusted EBITDA	$	176.8	$	299.7	$	(2.0)	$	61.9
Revenue per Ton	$	87.37	$	330.56	$	12.44	$	51.40
Costs per Ton	43.85		144.91		12.55		37.25
Adjusted EBITDA Margin per Ton	$	43.52	$	185.65	$	(0.11)	$	14.15

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	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

	Six Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal
	(Amounts in millions, except per ton data)
Tons sold	7.8		2.8		39.1		8.6
Revenue	$	606.1	$	855.1	$	480.9	$	428.0
Total Reporting Segment Costs	338.8		374.4		475.3		316.1
Adjusted EBITDA	$	267.3	$	480.7	$	5.6	$	111.9
Revenue per Ton	$	77.52	$	299.82	$	12.30	$	49.96
Costs per Ton	43.33		131.26		12.16		36.90
Adjusted EBITDA Margin per Ton	$	34.19	$	168.56	$	0.14	$	13.06

Available Free Cash Flow is defined as operating cash flow minus investing cash flow and distributions to noncontrolling interests; plus/minus changes to restricted cash and collateral (excluding one-time effects of the recent surety agreement amendment) 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, 2023
	(Dollars in millions)
Net cash provided by operating activities	$	739.7
- Net cash used in investing activities	(120.0)
- Distributions to noncontrolling interests	(22.8)
+/- Changes to restricted cash and collateral	39.7
- Anticipated expenditures or other requirements	—
Available Free Cash Flow	$	636.6

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, 2022. 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, 2022.

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Regulatory Matters - U.S.

National Ambient Air Quality Standards (NAAQS). The Clean Air Act (CAA) requires the United States Environmental Protection Agency (EPA) to review national ambient air quality standards every five years to determine whether revision to current standards are appropriate. On January 6, 2023, the EPA proposed to lower the allowable level of average annual primary particulate matter (PM). If enacted as proposed, this rule would require fossil fuel generating units to install additional nitrogen oxide (NOx) reducing technologies, ultimately increasing the cost of fossil fuel generated energy or causing potential unit retirements.

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.

On March 15, 2023, the EPA issued a final rule to address regional ozone transport by imposing new federal ozone season emission budgets for NOx in 23 states, including California, Nevada, Oklahoma and Texas, as well as some Indian reservation areas. The rule includes emission limits for NOx for 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. The rule has been challenged in several U.S. Courts of Appeal, including the U. S. Court of Appeals for the D.C. Circuit (D.C. Circuit).

EPA Regulation of Greenhouse Gas Emissions from New and Existing Fossil Fuel-Fired Electricity Utility Generating Units (EGUs). On May 23, 2023, the EPA proposed a rule that includes five separate actions regarding the control of greenhouse gas (GHG) emissions from fossil fuel-fired power plants. The EPA proposed to revise New Source Performance Standards (NSPS) to address carbon dioxide (CO2) emissions from both new fossil fuel-fired steam generating units and new fossil fuel-fired stationary combustion turbines. The EPA also proposed emission guidelines for existing coal- and oil/gas-fired steam generating units and for existing stationary combustion turbines. Finally, in the same proposed rule, the EPA proposed to repeal the Affordable Clean Energy Rule, promulgated by the EPA in 2019 and vacated by the D.C. Circuit in 2021.

If finalized in the form proposed, the regulations would require existing fossil fuel-fired steam generating units (primarily coal units) to use carbon capture and sequestration (CCS) with 90% capture of CO2 if they plan to operate after December 31, 2039. These units, however, may also pursue a different compliance pathway that is based on making a commitment to cease operations. The proposed rule also would require existing stationary combustion turbines over 300 megawatts with a capacity factor greater than 50% (primarily units using natural gas) to either utilize CCS by 2035 or pursue a pathway that would require co-firing with 30% low-GHG hydrogen by 2032, followed by co-firing with 96% low-GHG hydrogen by 2038. The EPA is also taking comments with regard to imposing standards for stationary combustion turbines under 300 megawatts.

All requirements related to existing affected units – whether fired by coal, oil or natural gas – will be imposed through state plans that can additionally take into account the remaining useful life of a generating unit when determining appropriate controls. The EPA, however, proposes that such plans generally be no less stringent than the emission reductions that would be obtained under the EPA’s guidelines. Existing steam generating units must start complying with the EPA’s proposed standards by January 1, 2030 and existing stationary combustion turbines by either January 1, 2032 or January 1, 2035 depending on what option for compliance is chosen.

Finally, as part of the proposed rule, any newly constructed steam generating unit or newly constructed stationary combustion turbine would be subject to GHG standards as of May 23, 2023, the date of the proposed rule. As proposed, any new fossil-fuel steam generating unit will need to comply with partial CCS upon startup as well as a requirement for 90% CO2 reduction through CCS by 2040. Any new or reconstructed stationary combustion turbine will be subject to different standards based on whether it is considered low load, intermediate load or a base load unit.

If finalized as proposed, the GHG NSPS could have substantial impacts on the use of coal, oil and natural gas for the generation of electricity.

40

Mercury and Air Toxic Standards (MATS). In 2012, the EPA published the final MATS rule, which revised the NSPS for NOx, sulfur dioxide and PM for new and modified coal-fueled electricity generating plants, and imposed maximum achievable control technology (MACT) emission limits on hazardous air pollutants (HAPs) from new and existing coal-fueled and oil-fueled electric generating plants. MACT standards limit emissions of mercury, acid gas HAPs, non-mercury HAP metals and organic HAPs.

On March 6, 2023, the EPA issued a final rule which reaffirmed its determination to regulate coal- and oil-fired EGUs under CAA section 112, including the regulation of HAPs from EGUs after considering cost. On April 3, 2023, the EPA proposed to amend the 2012 MATS rule and require an additional two-thirds reduction in the filterable PM emission of non-mercury HAP metals from existing coal-fired power plants as well as the usage of continuous emissions monitoring systems, among other proposals. Under the proposed rule, the EPA estimated that approximately 500 megawatts of coal-fired capacity would retire by 2028. The public comment period on the proposals ended on June 23, 2023.

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. On March 29, 2023, the EPA proposed a rule that would establish more stringent standards for flue gas desulfurization wastewater, bottom ash transport water and combustion residual leachate. If the proposed rule is finalized in substantially the same form, the revised effluent limitations guidelines would significantly increase costs for many coal-fueled steam electric power plants. Concurrently, the EPA issued a direct final rule which extended the deadline through June 2023 for steam electric power plants to commit to the permanent cessation of coal combustion by December 31, 2028 in exchange for less stringent wastewater discharge requirements during the interim. The direct final rule could influence fuel switching or additional coal generating unit retirements by the end of 2028.

Clean Water Act (CWA) Definition of “Waters of the United States”. On January 18, 2023, the EPA and the U.S. Army Corp of Engineers finalized a revised definition of “Waters of the United States” to clarify the scope of federal regulatory authority under the CWA. Several courts preliminarily enjoined that rule in 27 states. In addition, on May 25, 2023, the Supreme Court of the United States issued its decision in Sackett v. EPA, No. 21-454, which significantly narrowed the scope of federal regulatory authority over wetlands and non-navigable waters. The agencies have indicated that they are implementing the CWA consistent with the Sackett decision, and they may issue additional guidance or initiate another rulemaking proceeding to revise the 2023 rule.

Regulatory Matters - Australia

New South Wales Coal Directions. The State of New South Wales (NSW) 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 have been amended at various dates. The most recent directions require 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 impose additional reporting obligations to demonstrate compliance. While these directions are currently not anticipated to significantly impact the Wambo Mines or the Wilpinjong Mine, the nature and extent of those obligations and associated reporting requirements may continue to evolve if further directions are issued.

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.

On March 27, 2023, the Australian Federal Government announced several additional measures in the Safeguard Mechanism (Crediting) Amendments Bill 2023 which was introduced and passed both Houses of Parliament on March 30, 2023. The legislation introduces a cap on overall net emissions from facilities covered by the scheme through 2030. The legislation also sets a cap of net zero tonnes carbon dioxide equivalent for any financial year beginning after June 30, 2049. In addition, if the Minister for Environment and Water grants an approval under the Environment Protection and Biodiversity Conservation Act 1999 (Cth) (EPBC Act) to a new or expanded facility covered by the scheme, the Minister will be required to give an estimate of the facility's Scope 1 emissions to the Minister for Climate Change, the Climate Change Secretary and the Climate Change Authority for assessment against scheme targets. The legislation went into effect on July 1, 2023. The potential impact of these reforms to Peabody’s Australian operations is under review.

41

Risks Related to Global Climate Change

There have been no significant changes to the Company’s global climate matters subsequent to December 31, 2022. Refer to Part I, Item 1. “Business” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2022 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 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, 2023, the Company’s cash balances totaled $1,080.5 million, including approximately $676.4 million held by Australian subsidiaries, $380.9 million held by U.S. 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. From time to time, the Company may repatriate excess cash from its foreign subsidiaries to the U.S. During the six months ended June 30, 2023, the Company repatriated approximately $250 million through intercompany dividends. If additional 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 $1,317.8 million as of December 31, 2022 to $1,115.3 million as of June 30, 2023. Available liquidity was comprised of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Cash and cash equivalents	$	1,080.5	$	1,307.3
Credit facility availability	—		3.5
Accounts receivable securitization program availability	34.8		7.0
Total liquidity	$	1,115.3	$	1,317.8

Capital Returns to Shareholders

The Company repurchased approximately 8.9 million shares of its common stock for $184.2 million and paid dividends of $10.8 million during the three months ended June 30, 2023. Subsequent to June 30, 2023, the Company repurchased an additional 3.1 million shares for $67.0 million.

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 agreement, the Company was required to post collateral on a periodic basis through December 31, 2025. Prior to the April 2023 amendment, the Company had posted cumulative collateral of $557.8 million, primarily in the form of letters of credit.

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Under the April 2023 amendment, the Company and 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 represents a negotiated increase from the uncapped cumulative collateral amount prior to the amendment and may vary prospectively as future bonding levels increase or decrease. The amendment also removes restrictions on the payment of dividends and share repurchases, and extends the agreement through December 31, 2026. In order to maintain the new maximum collateral standstill, 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 $533.6 million at June 30, 2023. 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, which commenced for the second quarter of 2023. The Company granted second liens on $200.0 million of mining equipment under the original agreement, which remain in force under the April 2023 amendment.

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 credit agreement which, as amended, provided for $237.2 million of capacity for irrevocable standby letters of credit (LC Facility). The $223.8 million of letters of credit that were outstanding under the LC Facility at March 31, 2023 were subsequently cancelled and, in certain cases, replaced by cash-collateralized letters of credit or letters of credit issued under the Company’s accounts receivable securitization program.

Collateralized Letter of Credit Agreement

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 March 31, 2023, letters of credit of $168.2 million were outstanding under the agreement, which were collateralized by cash of $173.2 million.

Margin Requirements

From time to time, the Company enters into hedging arrangements, including economic hedging arrangements, to manage various risks, including coal price volatility. Most hedging arrangements require the Company to post margin with its clearing broker based on the value of the related instruments and other credit factors. If the fair value of its exchange-cleared hedge portfolio moves significantly, the Company could be required to post additional margin, which could negatively impact its liquidity.

During the six months ended June 30, 2023, the Company’s coal derivative contracts with margin requirements were settled and margin postings declined from $255.5 million at December 31, 2023 to zero at June 30, 2023.

Indebtedness

The Company’s total indebtedness as of June 30, 2023 and December 31, 2022 is presented in the table below.

Debt Instrument (defined below, as applicable)	June 30, 2023		December 31, 2022
	(Dollars in millions)
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0
Finance lease obligations	23.5		23.6
Less: Debt issuance costs	(9.0)		(9.8)
	334.5		333.8
Less: Current portion of long-term debt	13.0		13.2
Long-term debt	$	321.5	$	320.6

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During 2022, the Company utilized various methods allowable or required under its then-existing debt agreements to retire all of its senior secured long-term debt, leaving only the 3.250% Convertible Senior Notes due 2028 (the 2028 Convertible Notes), which are further described below, and various finance lease obligations outstanding at December 31, 2022.

The Company’s remaining indebtedness requires estimated contractual principal and interest payments, assuming interest rates in effect at June 30, 2023, of approximately $10 million in 2023, $23 million in 2024, $16 million in 2025, $13 million in 2026, $12 million in 2027 and $325 million thereafter.

Cash payments for interest related to the Company’s indebtedness and financial assurance instruments amounted to $40.6 million and $77.8 million during the six months ended June 30, 2023 and 2022, respectively.

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.

The Company used the proceeds of the offering of the 2028 Convertible Notes and available cash to redeem $62.6 million of senior secured notes maturing in 2024 and $257.4 million of senior secured notes maturing in 2025, and to pay related premiums, fees and expenses relating to the offering and redemptions.

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 will bear interest from March 1, 2022 at a rate of 3.250% per year payable semi-annually in arrears on March 1 and September 1 of each year, beginning on September 1, 2022.

During the first and second quarters of 2023, 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 2023, and will not be similarly convertible during the third quarter of 2023.

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.

Accounts Receivable Securitization Program

As described in Note 11. “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 secured overnight financing rate (SOFR). 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, 2023, the Company had no outstanding borrowings and $117.8 million of letters of credit outstanding under the program, which were primarily in support of portions of the Company’s reclamation obligations. The Company was not required to post cash collateral under the securitization program at June 30, 2023.

Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2023. The April 2023 termination of the Company’s credit agreement and related letter of credit facility eliminated the related compliance requirements as of March 31, 2023 and prospectively.

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Cash Flows

The following table summarizes the Company’s cash flows for the six months ended June 30, 2023 and 2022, 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,
	2023		2022
	(Dollars in millions)
Net cash provided by operating activities	$	739.7	$	9.4
Net cash (used in) provided by investing activities	(120.0)		94.5
Net cash (used in) provided by financing activities	(225.4)		75.1
Net change in cash, cash equivalents and restricted cash	394.3		179.0
Cash, cash equivalents and restricted cash at beginning of period	1,417.6		954.3
Cash, cash equivalents and restricted cash at end of period	$	1,811.9	$	1,133.3
Available Free Cash Flow	$	636.6

Operating Activities. The increase in net cash provided by operating activities for the six months ended June 30, 2023 compared to the same period in the prior year was driven by the year-over-year increase in operating cash flow from working capital fluctuations ($450.7 million), including the return of margin associated with derivative financial instruments ($255.5 million), and from the Company’s mining operations ($279.6 million).

Investing Activities. The increase in net cash used in investing activities for the six months ended June 30, 2023 compared to the same period in the prior year was driven by lower cash receipts from Middlemount ($142.2 million), higher capital expenditures and the payment of capital accruals ($54.9 million), and lower cash receipts from the disposal of assets ($11.4 million).

Financing Activities. The increase in net cash used by financing activities for the six months ended June 30, 2023 compared to the same period in the prior year was driven by the cash proceeds from common stock and debt issuances in the prior year ($222.0 million and $545.0 million, respectively) and common stock repurchases and dividends paid in the current year ($173.0 million and $10.8 million, respectively), partially offset by lower repayments of long-term debt ($650.0 million) in the current year.

Off-Balance-Sheet Arrangements

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.

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

	June 30, 2023						December 31, 2022
	Reclamation Support		Other Support (1)		Total		Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	1,119.0	$	113.1	$	1,232.1	$	1,250.1	$	126.7	$	1,376.8
Letters of credit	23.8		94.0		117.8		437.8		131.8		569.6
	1,142.8		207.1		1,349.9		1,687.9		258.5		1,946.4
Less: Letters of credit in support of surety bonds (2)	(23.8)		(5.9)		(29.7)		(431.7)		(37.2)		(468.9)
Obligations supported, net	$	1,119.0	$	201.2	$	1,320.2	$	1,256.2	$	221.3	$	1,477.5

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

At June 30, 2023, the Company had total asset retirement obligations of $753.5 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.

Not presented in the above table is approximately $925.4 million of restricted cash and other balances serving as collateral which are included in the accompanying condensed consolidated balance sheets at June 30, 2023, as described in Note 11. “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, mandatory repurchases of credit facility capacity, and amounts held directly with beneficiaries which are not supported by surety bonds.

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.

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, 2022. The Company’s critical accounting policies remain unchanged at June 30, 2023, and there have been no material changes in the Company’s critical accounting estimates.

Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented

Although there are new accounting pronouncements issued by the Financial Accounting Standards Board that the Company will adopt, as applicable, the Company does not believe any of these accounting pronouncements will have a material impact on its unaudited condensed consolidated financial statements or disclosures.

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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, 2023, the Company had approximately 109 million tons of U.S. thermal coal priced and committed for 2023. This includes approximately 91 million tons of PRB coal and 18 million tons of other U.S. thermal coal. The Company has the flexibility to increase volumes should demand warrant. Peabody is estimating full year 2023 thermal coal sales volumes from its Seaborne Thermal segment of 15 million to 16 million tons comprised of thermal export volume of 9.5 million to 10.5 million tons and domestic volume of 5.5 million tons. Peabody is estimating full year 2023 metallurgical coal sales from its Seaborne Metallurgical segment of 6.5 million to 7.5 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, 2023, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures, forwards and options. The Company classifies certain physical forward sales contracts as derivatives for which the normal purchase, normal sales exception does not apply.

Foreign Currency Risk

The Company has historically utilized currency forwards and options to hedge currency risk associated with anticipated Australian dollar expenditures. The accounting for these derivatives is discussed in Note 5. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements. As of June 30, 2023, the Company held average rate options with an aggregate notional amount of $486.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending March 31, 2024. As of June 30, 2023, the Company also held purchased collars with an aggregate notional amount of $514.0 million Australian dollars related to anticipated Australian dollar expenditures during the nine-month period ending March 31, 2024. 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 $199 million for the next twelve months. Based upon the Australian dollar/U.S. dollar exchange rate at June 30, 2023, the currency option contracts outstanding at that date would limit the Company’s exposure to approximately $160 million with respect to a $0.10 increase in the exchange rate and approximately $165 million with respect to a $0.10 decrease in the exchange rate for the next twelve months.

Diesel Fuel Price Risk

The Company expects to consume 90 to 100 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 $23 million based on its expected usage.

As of June 30, 2023, 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.

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, 2023, 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.

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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 12. “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. For information regarding 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 II of its Quarterly Report on Form 10-Q for the quarter ended March 31, 2023 filed with the SEC on May 4, 2023, and Item 1A. “Risk Factors” of Part I of its Annual Report on Form 10-K for the year ended December 31, 2022 filed with the SEC on February 24, 2023. 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.

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;

•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;

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•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 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;

•inflation could 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 such as the ongoing conflict between Russia and Ukraine;

•Peabody could be exposed to significant liability, reputational harm, loss of revenue, increased costs or other risks if it sustains cyber 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;

•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.

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

Issuances of Equity Securities

In June 2021, the Company announced an at-the-market equity offering program pursuant to which the Company could offer and sell up to 12.5 million shares of its common stock. The at-the-market equity offering program was further expanded to 32.5 million shares during 2021. The shares are offered and sold pursuant to the Company’s Registration Statement on Form S-3, which was declared effective by the Securities and Exchange Commission on April 23, 2021, as supplemented by prospectus supplements dated June 4, 2021, September 17, 2021, and December 17, 2021 relating to the offer and sale of the shares. Through June 30, 2023, the Company has sold approximately 24.8 million shares for net cash proceeds of $269.8 million. No sales were made under this at-the-market equity offering program during the six months ended June 30, 2023, leaving approximately 7.7 million shares available for sale.

On March 7, 2022, the Company entered into an at-the-market equity offering program pursuant to which the Company could offer and sell shares of its common stock having an aggregate gross sales price of up of $225 million. The shares were offered and sold pursuant to the Company’s Registration Statement on Form S-3, which was declared effective by the Securities and Exchange Commission on April 23, 2021, as supplemented by a prospectus supplement dated March 7, 2022 relating to the offer and sale of the shares. During the six months ended June 30, 2022, the Company sold approximately 10.1 million shares for net proceeds of $222.0 million, thereby concluding this at-the-market equity offering program.

Dividends

During the fourth quarter of 2020, the Company entered into a transaction support agreement with its surety bond providers which prohibited the payment of dividends through the earlier of December 31, 2025, or the maturity of the credit agreement unless otherwise agreed to by the parties to the agreement. Additionally, restrictive covenants in the Company’s credit facility also limited the Company’s ability to pay cash dividends. On April 14, 2023, the Company amended the existing transaction support agreement with the surety bond providers to remove the restrictions on shareholder returns, subject to a minimum liquidity threshold, and terminated the credit facility.

The declaration and payment of dividends and the amount of dividends will depend on the Company’s annual AFCF. Peabody anticipates a regular quarterly cash dividend of $0.075 per share, but all shareholder returns remain at the Board of Director's discretion.

During the three and six months ended June 30, 2023, the Company declared dividends per share of $0.075. On July 27, 2023, the Company declared a dividend per share of $0.075 to be paid on August 30, 2023 to shareholders of record as of August 10, 2023.

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.

Share Repurchase Program

Similar to the payment of dividends as described above, the same agreement with the Company’s surety bond providers prohibited share repurchases through the earlier of December 31, 2025, or the maturity of the credit agreement unless otherwise agreed to by the parties to the agreement. Additionally, restrictive covenants in its credit facility also limited the Company’s ability to repurchase shares. The April 14, 2023 amendment and termination of the credit facility as described above, allow share repurchases subject to the Company’s annual AFCF.

On August 1, 2017, the Company announced that its Board of Directors authorized a share repurchase program to allow repurchases of up to $500 million of the then outstanding shares of its common stock and/or preferred stock (2017 Repurchase Program), which was eventually expanded to $1.5 billion during 2018. Prior to the suspension of the 2017 Repurchase Program, as discussed below, the Company repurchased 41.5 million shares of its common stock under the 2017 Repurchase Program for $1,340.3 million, which included commissions paid of $0.8 million. 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. The 2017 Repurchase Program was superseded and replaced by the 2023 Repurchase Program.

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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 manner, timing, pricing, and amount 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, 2023, the Company had repurchased 8.9 million shares of its common stock under the 2023 Repurchase Program for $184.2 million, which included $11.2 million of unsettled share repurchases and commissions paid of $0.2 million, leaving $816.0 million available for share repurchase. Subsequent to June 30, 2023, the Company has purchased an additional 3.1 million shares of its common stock for $67.0 million.

Purchases of Equity Securities

The following table summarizes all share purchases for the three months ended June 30, 2023:

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, 2023	1,020	$	25.39	—	$	1,000.0
May 1 through May 31, 2023	3,111,429	21.34		3,111,429	933.6
June 1 through June 30, 2023	5,812,999	20.31		5,785,498	816.0
Total	8,925,448	20.67		8,896,927

(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, 2023, none of Peabody’s directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as those terms are defined in Item 408 of Regulation S-K.

Supplemental Employee Retirement Account Plan

On August 3, 2023, the Compensation Committee of the Board of Directors adopted the Peabody Investments Corp. 2023 Supplemental Employee Retirement Account plan (the SERA). The SERA is designed to allow a select group of highly compensated management employees, including Peabody’s executive officers, to make contributions in excess of certain limits imposed by the Internal Revenue Code that apply to Peabody’s tax-qualified 401(k) plan, and to receive matching contributions on such employee contributions. The effective date of the SERA is October 1, 2023.

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
10.1†	Peabody Investments Corp. 2023 Supplemental Employee Retirement Account.
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.

52

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 3, 2023	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)

53

EX-10.1

Exhibit 10.1

PEABODY INVESTMENTS CORP. 2023

SUPPLEMENTAL EMPLOYEE RETIREMENT ACCOUNT

WHEREAS, Peabody Investments Corp. (the “Company”) hereby adopts the Peabody Investments Corp. 2023 Supplemental Employee Retirement Account (the “Plan”), effective as of October 1, 2023, as may be amended, in accordance with the terms thereof (the “Effective Date”), as set forth herein; and

WHEREAS, the Plan is adopted for the benefit of a select group of management or highly compensated employees of the Company and its subsidiaries or affiliates, within the meaning of the Employee Retirement Income Security Act of 1974, as amended (“ERISA”), whose benefits under the Peabody Investments Corp. Employee Retirement Account are limited by the provisions of Section 401(a)(17) or 415 of the Internal Revenue Code of 1986; and

NOW, THEREFORE, effective as of the Effective Date, the Plan is hereby adopted as set forth herein.

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PEABODY INVESTMENTS CORP. 2023 SUPPLEMENTAL EMPLOYEE RETIREMENT ACCOUNT

TABLE OF CONTENTS

Page

SECTION 1 - NAME OF PLAN AND ESTABLISHMENT    4

SECTION 2 - DEFINITIONS    5

2.1Basic Plan    5

2.2Board    5

2.3Cause    5

2.4Code    5

2.5Committee    5

2.6Company    5

2.7Compensation    5

2.8Controlled Group    5

2.9Effective Date    5

2.10Employee    6

2.11Employer    6

2.12ERISA    6

2.13Normal Retirement Date    6

2.14Participant    6

2.15Plan    6

2.16Plan Administrator    6

2.17Plan Year    6

2.18Valuation Date    6

2.19Years of Service    6

SECTION 3 - ELIGIBILITY    7

3.1Participants    7

3.2Cessation Of Participation    7

SECTION 4 - CREDITS    8

4.1Deferral Credits    8

4.2Employer Matching Credits    8

4.3Performance Credits    8

4.4Discretionary Credits    8

4.5Elections    9

4.6Change in Contributions to Basic Plan    9

SECTION 5 - ALLOCATION    9

5.1Establishment Of Accounts    9

5.2Crediting Earnings or Losses    9

5.3Source of Payments    10

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SECTION 6 - EARNINGS ON ACCOUNTS    11

6.1Investment Funds    11

6.2Participant’s Selection of Investment Fund    11

6.3Deemed Transfers Between Investment Funds    11

6.4Investments and Charges    11

SECTION 7 - DISTRIBUTIONS AT TERMINATION OF EMPLOYMENT (VESTING)    12

7.1Distributions Upon Termination of Employment    12

7.2Determination Of Vested Portion    12

7.3Forfeitures    12

SECTION 8 - DISTRIBUTIONS AT DEATH    13

8.1Distributions Upon Death    13

8.2Designation Of Beneficiary    13

8.3Beneficiary Not Designated    13

8.4Divorce    13

8.5Survival of Beneficiary and Simultaneous Death    14

8.6Death Due to Criminal Act    14

SECTION 9 – ADMINISTRATION    15

9.1Plan Administrator    15

9.2Construction    15

9.3Delegation By the Plan Administrator    15

9.4Records Of the Plan Administrator    15

9.5Committee    15

9.6Decisions By the Committee    16

9.7Meetings Of The Committee    16

9.8Expenses    16

SECTION 10 - CLAIM PROCEDURES    17

10.1Claim    17

10.2Claim Decision    17

10.3Request For Review    17

10.4Review Of Decision    18

SECTION 11 - AMENDMENT AND TERMINATION    20

11.1Amendment    20

11.2Termination; Discontinuance of Credits    20

SECTION 12 - MISCELLANEOUS    21

12.1Participants’ Rights    21

12.2Spendthrift Clause    21

12.3Delegation Of Authority by Employer    21

12.4Distributions To Minors    21

12.5Construction Of Plan    21

12.6Gender, Number and Heading    21

12.7Separability Of Provisions    22

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12.8Service Of Process    22

12.9Qualified Domestic Relations Order    22

12.10No Trust    22

12.11Section 409A Compliance    22

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PEABODY INVESTMENTS CORP. 2023 SUPPLEMENTAL EMPLOYEE RETIREMENT ACCOUNT

SECTION 1 - NAME OF PLAN AND ESTABLISHMENT

This Plan shall be known as the “Peabody Investments Corp. 2023 Supplemental Employee Retirement Account.” The Plan is adopted for the benefit of a select group of management or highly compensated employees of the Company and its subsidiaries or affiliates, within the meaning of ERISA.

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SECTION 2 - DEFINITIONS

2.1Basic Plan.

“Basic Plan” means the Peabody Investments Corp. Employee Retirement Account.

2.2Board.

“Board” means the board of directors of the Company or of any successor by merger, purchase or otherwise.

2.3Cause.

“Cause” means (a) commission of an act of fraud, dishonesty, theft or embezzlement involving the Employer, (b) repeated gross neglect of, continual inattention to, or nonperformance of, duties for and on behalf of the Employer or refusal to adhere to the reasonable policies and regulations established by the Employer, (c) repeated personal misconduct of a nature seriously compromising the Employee’s ability to perform assigned duties, or (d) repeated insubordination. Whether an Employee is terminated for Cause shall be determined based on evidence presented to the satisfaction of a majority of the Committee.

2.4Code.

“Code” means the Internal Revenue Code of 1986, as amended.

2.5Committee.

“Committee” means the Committee appointed pursuant to Section 10.5.

2.6Company.

“Company” has the meaning given to such term in the preamble.

2.7Compensation.

“Compensation” means gross salary earned by an Employee with respect to services performed during the Plan Year. Compensation excludes incentive compensation, payments from any deferred compensation arrangement, compensation that is not US-sourced income, and payments made during an Employee’s long-term disability.

2.8Controlled Group.

“Controlled Group” means the Company and all other entities required to be aggregated with the Company under Sections 414(b) or (c) of the Code.

2.9Effective Date.

“Effective Date” has the meaning given to such term in the preamble.

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2.10Employee.

“Employee” means any person who is classified by the Employer as an employee. An individual not classified as an employee shall not be considered an Employee regardless of whether such individual is a common law employee or is classified as an employee for tax, employment law or other purposes.

2.11Employer

“Employer” means the Company or any other member of the Controlled Group which has, with the consent of the Board, adopted the Plan, as amended from time to time.

2.12ERISA.

“ERISA” has the meaning given to such term in the preamble.

2.13Normal Retirement Date.

“Normal Retirement Date” means the date on which a Participant terminates his or her employment with the Employer (except by death) provided such date is on or after his or her attainment of age 62.

2.14Participant.

“Participant” means a person (a) who is an Employee who has satisfied the eligibility requirements of Section 3 on or after the Effective Date and (b) who has not become a former Participant under Section 3.2.

2.15Plan.

“Plan” has the meaning given to such term in the preamble.

2.16Plan Administrator.

“Plan Administrator” means Peabody Investments Corp.

2.17Plan Year.

“Plan Year” means the 12-month period commencing on January 1 and ending on December 31.

2.18Valuation Date.

“Valuation Date” means any business day the New York Stock Exchange is open for trading.

2.19Years of Service.

“Years of Service” means years of service as credited under the Basic Plan.

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SECTION 3 - ELIGIBILITY

3.1Participants.

With respect to any Plan Year (hereinafter referred to in this Section 3.1 as the “current Plan Year”), each Employee (1) who is a member of a select group of management or highly compensated employees of the Employer, within the meaning of ERISA, (2) who is eligible to participate in the Basic Plan, (3) who is employed at the level of vice president, general manager or above on December 31 of the Plan Year immediately preceding the current Plan Year (or (A) in the case of a newly hired Employee who commences employment with the Employer during the current Plan Year, who is employed at the level of vice president, general manager or above, or (B) in the case of any other Employee who has not previously been a Participant, who is promoted to a position at the level of vice president, general manager or above during the current Plan Year), and (4) who is notified in writing by the Plan Administrator of his or her eligibility to participate in the Plan, shall be eligible:

(a)to elect to defer his or her Compensation in accordance with Section 4.1;

and

(b)for Employer matching credits under Section 4.2 and performance credits

under Section 4.3;

for the current Plan Year.

3.2Cessation Of Participation.

A person shall cease to be a Participant and shall become a former Participant when he or she

(a)has ceased to be employed by the Employer, and

(b)has no undistributed account balances under the Plan; provided, however, that an Employee shall not be eligible for credits under Section 4 for any Plan Year with respect to which the Employee does not satisfy the applicable requirements of Section 3.1.

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SECTION 4 - CREDITS

4.1Deferral Credits.

A Participant may elect to have from 1% to 10% of his or her Compensation deferred and credited by the Employer to the Plan to the extent such amount (a) exceeds the amount of Compensation which the Participant was entitled to contribute to the Basic Plan under the limits of Section 401(a)(17) of the Code, or (b) would exceed the amount of Compensation which the Participant would be entitled to contribute to the Basic Plan under the limits of Section 415 of the Code, determined on the basis of the Participant’s elections in effect under the Basic Plan on the first day of the Plan Year and without regard to any changes in such elections on or after the first day of such Plan Year (or, in the case of a newly hired Participant who commences employment with the Employer during a Plan Year, the day such Participant makes his or her election with respect to such Plan Year), provided, however that no such election with respect to the Section 415 limit shall apply unless and until the Participant’s elective deferrals under the Basic Plan reach the limit of Section 402(g) of the Code with respect to such Plan Year.

4.2Employer Matching Credits.

The Employer will credit to the Plan an amount equal to 100% of the first 6% of his or her Compensation that the Participant elects to have deferred and credited to the Plan under Section 4.1.

4.3Performance Credits.

(a)Participants Employed on Last Day of Plan Year. In addition to any amounts credited to the Plan by the Employer pursuant to Section 4.2, the Employer may credit to the Plan for the Plan Year such amount, if any, as the Board in its sole discretion shall determine. Such amount shall be credited to each Participant described in Section 3.1(a) or

(b)who is employed on the last day of such Plan Year in proportion to the relationship which the Compensation of the Participant for the Plan Year bears to the total Compensation of all eligible Participants for the Plan Year to the extent such amount exceeds the amount of Compensation which the Participant was entitled to have the Employer contribute on his or her behalf to the Basic Plan, if any, under the limits of Sections 401(a)(17) and 415 of the Code.

(b) Timing of Credits. Any amounts described in this Section 4.3 shall be credited to the Plan as soon as practicable following the determination by the Board that a performance contribution will be made for the Plan Year.

4.4Discretionary Credits.

For any Plan Year, the Employer may credit to the Plan for one (1) or more Participants an amount determined by the Employer in its sole discretion for each such Participant. Nothing herein shall require the Employer to credit (i) any such amount for any Plan Year, (ii) the same amount, either as a dollar amount or a percentage of Compensation, for all such Participants, or (iii) any amount for any particular Participant. The fact that a Participant is credited with an amount under

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this Section 4.4 for any Plan Year shall not entitle that Participant to be credited with any such amount for any subsequent Plan Year.

4.5Elections.

Each election by a Participant under Section 4.1 for a Plan Year must be made prior to the beginning of the Plan Year in accordance with the rules and procedures established by the Plan Administrator; provided, however, that (i) in the case of a newly hired Participant described in Section 3.1(a)(3)(A) who commences employment with the Employer during the current Plan Year, such election may be made within thirty (30) days after the date the Participant commences such employment, and (ii) in the case of a newly eligible Participant described in Section 3.1(a)(3)(B) who is promoted to a position at the level of vice president, general manager or above during the current Plan Year, such election may be made within thirty (30) days after the date such Participant is promoted. Any such election shall be effective and irrevocable for such Plan Year (or, in the case of a newly hired or newly eligible Participant, for the portion of the Plan Year following such election), and shall remain in effect for subsequent Plan Years in which the Participant continues to satisfy the requirements of Section 3.1 unless the Participant makes a new election with respect to any such Plan Year in accordance with this Section 4.5.

4.6Change in Contributions to Basic Plan.

Notwithstanding anything herein to the contrary, the amount credited to any Participant under Section 4.3 shall be determined without regard to any changes in such Participant’s elections under the Basic Plan on or after the first day of the Plan Year to the extent any such change would cause a change in the amount credited under Section 4.3 in excess of the limit under Section 402(g)(1)(A), (B) and (C) in effect for such Plan Year.

SECTION 5 - ALLOCATION

5.1Establishment Of Accounts.

The Plan Administrator shall establish and maintain for each Participant a Pre-Tax Matched Account, a Pre-Tax Unmatched Account, a Company Pre-Tax Matching Account, a Performance Credit Account and a SERA Discretionary Account. All amounts by which an Employee elects to have his or her salary deferred under Section 4.1 up to the applicable percentage of Compensation set forth in Section 4.2 shall be credited to his or her Pre-Tax Matched Account, all amounts by which an Employee elects to have his or her salary deferred under Section 4.1 in excess of the applicable percentage set forth in Section 4.2 shall be credited to his or her Pre-Tax Unmatched Account, all Employer credits under Section 4.2 shall be credited to his or her Company Pre-Tax Matching Account, all Employer credits under Section 4.3 shall be credited to his or her Performance Credit Account, and all Employer credits under Section 4.4 shall be credited to his or her SERA Discretionary Account.

5.2Crediting Earnings or Losses.

All earnings or losses shall be based on appreciation or depreciation in the fair market value of the investment funds in which the Participant is deemed to have invested his or her accounts

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under Section 6 and shall be credited to accounts based on account balances on each Valuation Date.

5.3Source of Payments.

Notwithstanding anything herein to the contrary, the payments to any Participant or beneficiary under the Plan shall be made from assets which shall continue, for all purposes, to be a part of the general, unrestricted assets of the Employer; no person shall have any interest in any such assets by virtue of the provisions of this Plan. The Employer’s obligation hereunder shall be an unfunded and unsecured promise to pay money in the future. To the extent that any person acquires a right to receive payments from the Employer under the provisions of this Plan, such right shall be no greater than the right of any unsecured general creditor of the Employer; no such person shall have nor acquire any legal or equitable right, interest or claim in or to any property or assets of the Employer.

In the event that, in its discretion, the Employer purchases an insurance policy or policies insuring the life of any Participant (or any other property) or establishes a rabbi trust to allow the Employer to recover the cost of providing benefits, in whole or in part, hereunder, neither the Participant nor any beneficiary hereunder shall have any rights whatsoever therein or in the proceeds therefrom. The Employer shall be the sole owner and beneficiary of any such insurance policy, rabbi trust or other property and shall possess and may exercise all incidents of ownership therein. No such policy, policies, assets of a rabbi trust or other property shall be held in any trust for the Participants, any beneficiary or any other person or as collateral security for any obligation of the Employer hereunder.

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SECTION 6 - EARNINGS ON ACCOUNTS

6.1Investment Funds.

A Participant may elect to have earnings or losses credited on all of his or her accounts as if such accounts had been invested in such funds as are made available from time to time under the Basic Plan.

6.2Participant’s Selection of Investment Fund.

Each Participant shall designate in 1% increments the percentages of amounts credited to his or her accounts under Section 4 for such Plan Year which are to be treated as if invested among the applicable investment funds. Such a designation shall be made in accordance with the rules and procedures established by Plan Administrator. Any such designation shall continue in effect for successive Plan Years unless changed in the same manner by the Participant. If any Participant fails to designate investment funds under this Section 6.2, amounts credited to his or her accounts under this Plan shall be treated as if invested in the applicable investment funds designated by the Participant for his or her contributions to the Basic Plan; provided, however, that in the case of a Participant who has not made an election to contribute to the Basic Plan, but for whom Employer credits under Section 4.3 or 4.4 have been credited to the Participant’s Performance Credit Account or SERA Discretionary Account, such credits or amount will be treated as if invested in the default investment fund designated by the Committee with respect to the Basic Plan unless the Participant designates a different investment fund in accordance with this Section 6.2 or makes a deemed transfer of such portion of his or her accounts to a different investment fund in accordance with Section 6.3.

6.3Deemed Transfers Between Investment Funds.

A Participant may elect in accordance with the rules and procedures established by the Plan Administrator to make a deemed transfer of all or any portion of his or her accounts that is treated as if invested in an investment fund by designating that such amount be treated as if subsequently invested in any other investment fund.

6.4Investments and Charges.

Nothing in this Section 6 shall require the Employer to actually invest any amount credited to a Participant’s accounts in accordance with the Participant’s election; provided, however, that if the Employer in its sole discretion does make any such investment in order to assist it in the meeting of its liabilities under the Plan, the Participant’s accounts shall be reduced for any charges imposed by the applicable investment fund.

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SECTION 7- DISTRIBUTIONS AT TERMINATION OF EMPLOYMENT (VESTING)

7.1Distributions Upon Termination of Employment.

A Participant whose employment with the Employer is terminated, prior to the earlier of his or her death or Normal Retirement Date shall receive the vested portion of his or her accounts in a lump sum. Such distribution shall be made on the later of:

(a)the date which is six (6) months after the date of the Participant’s termination of employment; and

(b)January 31 of the calendar year immediately following the calendar year in which the Participant’s termination of employment occurs;

or as soon as administratively feasible thereafter, but in no event later than the last day of the calendar year in which the date on which such distribution would be made in accordance with the foregoing occurs. A distribution hereunder shall be based on the value of the Participant’s accounts as of the Valuation Date as of which such distribution is being made.

7.2Determination Of Vested Portion.

(a)A Participant’s Pre-Tax Matched Account, Pre-Tax Unmatched Account and Performance Credit Account shall be 100% vested and nonforfeitable at all times.

(b)A Participant’s Company Pre-Tax Matching Account shall be 100% vested and nonforfeitable at all times.

(c)The portion of a Participant’s SERA Discretionary Account which shall be vested and nonforfeitable shall be determined in accordance with a separate agreement entered into with the Participant.

(d)Notwithstanding any provision herein to the contrary, a Participant’s accounts shall be 100% vested and nonforfeitable upon such Participant’s death or Normal Retirement Date.

7.3Forfeitures.

The nonvested portion of the SERA Discretionary Account of a Participant whose employment with the Employer is terminated prior to the earlier of his or her death or Normal Retirement Date shall be forfeited immediately when such Participant has terminated employment.

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SECTION 8 - DISTRIBUTIONS AT DEATH

8.1Distributions Upon Death.

Upon the death of a Participant while in the employment of the Employer, the Participant’s accounts shall become fully vested if not already fully vested) and shall be distributed in a lump sum to his or her beneficiaries in accordance with Sections 9.2 and 9.3. Upon the death of a Participant after termination of his or her employment with the Employer but prior to distribution under Section 7 or 8 being made, the vested portion of the Participant’s account balances shall be distributed in a lump sum to his or her beneficiaries in accordance with Sections 9.2 and 9.3. Such distribution shall be made fifteen (15) days following the date of the Participant’s death or as soon as administratively feasible thereafter, but in no event later than the last day of the calendar year in which the date on which such distribution would be made in accordance with the foregoing occurs or, if later, the 15th day of the third calendar month following such date. A distribution hereunder shall be based on the value of the Participant’s accounts as of the Valuation Date as of which such distribution is being made.

8.2Designation Of Beneficiary.

Each Participant shall have the right to name and change primary and contingent beneficiaries under the Plan in accordance with the rules and procedures established by the Plan Administrator. Upon the death of the Participant, the vested balance of his or her accounts shall be divided among the primary or contingent beneficiaries designated by such Participant who survive the Participant.

8.3Beneficiary Not Designated.

In the event the Participant has either failed to designate a beneficiary or no designated beneficiary survives him or her, the amounts otherwise payable to a beneficiary under the provisions of this Section shall be paid to the Participant’s surviving spouse or, if the Participant is not survived by his or her spouse, to the Participant’s executor or administrator.

8.4Divorce.

Unless the Participant has indicated otherwise on the beneficiary designation under Section 9.2, any designation of a beneficiary identified as the Participant’s Spouse shall be deemed revoked by the divorce of the Participant and his or her Spouse. Such revocation shall be effective upon receipt of acceptable documentary evidence of such divorce by the Company, the Plan Administrator or the Plan’s recordkeeper, whether before or after the Participant’s death; provided, however, that the Plan, the Company, the Plan Administrator and Plan’s recordkeeper shall not be liable for any payment or transfer made to a Participant’s former Spouse, whether pursuant to designation by the Participant under Section 9.2, prior to the receipt of such documentation. Notwithstanding the foregoing, any domestic relations order submitted to the Company, the Plan Administrator or the Plan’s recordkeeper at any time prior to the final transfer and/or payment of the Participant’s account shall be deemed to constitute such acceptable documentary evidence of divorce; provided, however, that this Section 9.4 shall not affect the rights of the Participant’s former Spouse under any such domestic relations order that is determined to be qualified pursuant to Section 13.9.

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8.5Survival of Beneficiary and Simultaneous Death.

Any person or persons designated as a beneficiary under Section 9.2 must be alive, and any entity designated as a beneficiary must be in existence, at the time of the Participant’s death in order to receive any undistributed amounts credited to the Participant’s accounts. To the extent permitted under the Code and ERISA, in the event that the order of the deaths of the Participant and any beneficiary designated under Section 9.2 cannot be determined, or have occurred within 120 hours of each other, the Participant shall be deemed to have survived the beneficiary.

8.6Death Due to Criminal Act.

In the event that the death of the Participant or any beneficiary designated under Section

9.2 is the result of a criminal act involving any other beneficiary so designated, any such beneficiary or beneficiaries convicted of such criminal act shall not be entitled to receive any undistributed amounts credited to the Participant’s accounts.

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SECTION 9 – ADMINISTRATION

9.1Plan Administrator.

The Company shall be the Plan Administrator of the Plan within the meaning of ERISA, and, except as otherwise specifically set forth herein, shall be solely responsible for and have sole control of the operation and administration of the Plan and the establishment of such procedures and processes as may be necessary for the efficient operation and administration of the Plan.

9.2Construction.

The Plan Administrator shall have the discretionary authority to construe, interpret and administer all provisions of the Plan and to determine a Participant’s eligibility for benefits on a uniform, non-discriminatory basis in similar fact situations.

9.3Delegation By the Plan Administrator.

The Plan Administrator may appoint such agents as it may deem necessary for the effective exercise of its duties, and may, to the extent not inconsistent herewith, delegate to such agents any powers and duties, both ministerial and discretionary, as the Plan Administrator may deem expedient or appropriate.

9.4Records Of the Plan Administrator.

All acts and determinations of the Plan Administrator shall be duly recorded, and all such records, together with such other documents as may be necessary for the proper administration of the Plan, shall be preserved in the custody of the Plan Administrator, such records and documents shall at all times be open for inspection and copying by any person designated by the Board.

9.5Committee.

The Board shall appoint a Committee of one (1) or more persons who shall serve without remuneration at the pleasure of the Board to review claims determinations in accordance with Sections 11.3 and 11.4 and to perform such other duties as may be delegated to it by the Plan Administrator. Upon death, resignation, removal or inability of a member of the Committee to continue, the Board shall appoint a successor. The Committee shall appoint its own Chairman from among the regular members of the Committee and shall also appoint a Secretary who may be, but need not be, a member of the Committee. The Chief Executive Officer of the Company may appoint persons as alternate members for designated regular members of the Committee for the sole and limited purpose of acting in place of such regular member at a Committee meeting called under Section 10.7 which such regular member is unable to attend. Alternate members shall serve without remuneration at the pleasure of the Chief Executive Officer. If, at any time, the Board has not appointed a Committee, or there is no Committee, then the Plan Administrator shall exercise all of the duties, responsibilities, powers and authorities given to the Committee.

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9.6Decisions By the Committee.

A decision of the Committee may be made by a written document signed by a majority of the members of the Committee or by majority vote at a meeting of the Committee. The Secretary of the Committee shall keep all records of meetings and of any action by the Committee and any and all other records desired by the Committee. No member of the Committee shall make any decision or take any action covering exclusively his or her own benefits under the Plan. All such matters shall be decided by a majority of the remaining members of the Committee or, in the event of inability to obtain a majority, by the Board.

9.7Meetings Of The Committee.

The Committee shall hold meetings upon such notice, at such place or places and at such times as the Committee may determine. Meetings may be called by the Chairman or any member of the Committee. A majority of the Committee shall constitute a quorum for the transaction of business.

9.8Expenses.

Any expense incurred by the Plan Administrator or the Committee with respect to employment of agents, attorneys or other persons shall be paid by the Employer.

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SECTION 10 - CLAIM PROCEDURES

10.1Claim.

A Participant, beneficiary or other person who believes that he or she is being denied a benefit to which he or she is entitled (hereinafter referred to as “Claimant”), or his or her duly authorized representative, may file a written request for such benefit with the Plan Administrator, setting forth his or her claim. The request must be addressed to:

Director, Total Rewards

Peabody Investments Corp. Supplemental Employee Retirement Account 701 Market Street

St. Louis, Missouri 63101-1826

10.2Claim Decision.

Upon receipt of a claim, the Director, Total Rewards shall advise the Claimant that a reply will be forthcoming within a reasonable period of time, but ordinarily not later than ninety (90) days, and shall, in fact, deliver such reply in writing within such period. However, the Director, Total Rewards may extend the reply period for an additional ninety (90) days for reasonable cause. If the reply period will be extended, the Director, Total Rewards shall advise the Claimant in writing during the initial ninety (90)-day period indicating the special circumstances requiring an extension and the date by which the Director, Total Rewards expects to render the benefit determination. If the claim is denied in whole or in part, the Director, Total Rewards will render a written opinion, using language calculated to be understood by the Claimant, setting forth:

(a)the specific reason or reasons for the denial;

(b)the specific references to pertinent Plan provisions on which the denial is

based;

(c)a description of any additional material or information necessary for the

Claimant to perfect the claim and an explanation why such material or such information is necessary;

(d)appropriate information as to the steps to be taken if the Claimant wishes to submit the claim for review, including a statement of the Claimant’s right to bring a civil action under Section 502(a) of ERISA following an adverse benefit determination on review; and

(e)the time limits for requesting a review of the denial under Section 11.3 hereof and for the actual review of the denial under Section 11.4 hereof.

10.3Request For Review.

Within sixty (60) days after the receipt by the Claimant of the written opinion described above, the Claimant may request in writing that the Committee review the Director, Total Rewards’ prior determination. Such request must be addressed to:

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Peabody Investments Corp. Supplemental Employee Retirement Account 701 Market Street

St. Louis, Missouri 63101-1826

The Claimant or his or her duly authorized representative may submit written comments, documents, records or other information relating to the denied claim, which such information shall be considered in the review under this subsection without regard to whether such information was submitted or considered in the initial benefit determination. The Claimant or his or her duly authorized representative shall be provided, upon request and free of charge, reasonable access to, and copies of, all documents, records and other information which (a) was relied upon by the Director, Total Rewards in making the initial claims decision, (b) was submitted, considered or generated in the course of the Director, Total Rewards making the initial claims decision, without regard to whether such instrument was actually relied upon by the Director, Total Rewards in making the decision or (c) demonstrates compliance by the Director, Total Rewards with the administrative processes and safeguards designed to ensure and to verify that benefit claims determinations are made in accordance with governing Plan documents and that, where appropriate, the Plan provisions have been applied consistently with respect to similarly situated claimants. If the Claimant does not request a review of the Director, Total Rewards’ determination by the Committee within such sixty (60)-day period, he or she shall be barred and estoppel from challenging such determination.

10.4Review Of Decision.

Within a reasonable period of time, ordinarily not later than sixty (60) days, after the Committee’s receipt of a request for review, it will review the Director, Total Rewards’ determination. If special circumstances require that the sixty (60)-day time period be extended, the Committee will so notify the Claimant within the initial sixty (60)-day period indicating the special circumstances requiring an extension and the date by which the Committee expects to render its decision on review, which shall be as soon as possible but not later than 120 days after receipt of the request for review. In the event that the Committee extends the determination period on review due to a Claimant’s failure to submit information necessary to decide a claim, the period for making the benefit determination on review shall not take into account the period beginning on the date on which notification of extension is sent to the Claimant and ending on the date on which notification of extension is sent to the Claimant and ending on the date on which the Claimant responds to the request for additional information. The Committee has discretionary authority to determine a Claimant’s eligibility for benefits and to interpret the terms of the Plan. Benefits under the Plan will be paid only if the Committee decides in its discretion that the Claimant is entitled to such benefits. The decision of the Committee shall be final and non-reviewable, unless found to be arbitrary and capricious by a court of competent review. Such decision will be binding upon the Employer and the Claimant.

If the Committee makes an adverse benefit determination on review, the Committee will render a written opinion, using language calculated to be understood by the Claimant, setting forth:

(a)the specific reason or reasons for the denial;

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(b)     the specific references to pertinent Plan provisions on which the denial is based;

(c)     a statement that the Claimant is entitled to receive, upon request and free of

charge, reasonable access to, and copies of, all documents, records and other information which (i) was relied upon by the Committee in making its decision, (ii) was submitted, considered or generated in the course of the Committee making its decision, without regard to whether such instrument was actually relied upon by the Committee in making its decision or (iii) demonstrates compliance by the Committee with its administrative processes and safeguards designed to ensure and to verify that benefit claims determinations are made in accordance with governing Plan documents, and that, where appropriate, the Plan provisions have been applied consistently with respect to similarly situated claimants; and

(d)    a statement of the Claimant’s right to bring a civil action under Section 502(a) of ERISA following the adverse benefit determination on such review.

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SECTION 11 - AMENDMENT AND TERMINATION

11.1Amendment.

The Company shall have the right, by a resolution adopted by action of the Board or anyone to whom corporate authority to amend the Plan has been delegated by the Board, at any time and from time to time to amend, in whole or in part, any or all of the provisions of the Plan. No such amendment, however, shall cause any reduction in the amount credited to any Participant’s account.

11.2Termination; Discontinuance of Credits.

The Company shall have the right at any time to terminate this Plan. Upon termination, partial termination, or complete discontinuance of credits, all Participants’ accounts (or, in the case of a partial termination, the accounts of all affected Participants) shall become fully vested and shall not thereafter be subject to forfeiture.

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SECTION 12 - MISCELLANEOUS

12.1Participants’ Rights.

Neither the establishment of the Plan hereby created, nor any modification thereof, nor the creation of any fund or account, nor the payment of any benefits, shall be construed as giving to any Participant or other person any legal or equitable right against the Employer, any officer or Employee thereof or the Board except as herein provided. Under no circumstances shall the terms of employment of any Participant be modified or in any way affected hereby.

12.2Spendthrift Clause.

No benefit or beneficial interest provided under the Plan shall be subject in any manner to anticipation, alienation, sale, transfer, assignment, pledge, encumbrance or charge, either voluntary or involuntary, and any attempt to so alienate, anticipate, sell, transfer, assign, pledge, encumber or charge the same shall be null and void. No such benefit or beneficial interest shall be liable for or subject to the debts, contracts, liabilities, engagements, or torts of any person to whom such benefits or funds are or may be payable.

Notwithstanding the foregoing, if at such time as the Participant or his or her beneficiary becomes entitled to benefit payments hereunder, the Participant has any debt, obligation or other liability representing an amount owing to the Company or any other Employer, and if such debt, obligation or other liability is due and owing at the time benefit payments are payable hereunder, the Company may offset the amount owed it or the other Employer against the amount of benefits otherwise payable hereunder.

12.3Delegation Of Authority by Employer.

Whenever the Employer, under the terms of this Plan, is permitted or required to do or perform any act, it shall be done and performed by any officer duly authorized by the board of directors of the Employer.

12.4Distributions To Minors.

In the event that any portion of the Plan becomes distributable to a minor or other person under legal disability (as determined by the laws of the jurisdiction in which he or she then resides), the Plan Administrator shall direct that such distribution be made to the legal representative of such minor or other person.

12.5Construction Of Plan.

This Plan shall be construed according to the laws of the State of Missouri, and all provisions of the Plan shall be administered according to the laws of such state.

12.6Gender, Number and Heading.

Whenever any words are used herein in the masculine gender, they shall be construed as though they were also used in the feminine gender in all cases where they would so apply, and

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                     21

wherever any words are used herein in the singular form, they shall be construed as though they were also used in the plural form in all cases where they would so apply. Headings of sections and subsections are inserted for convenience of reference, constitute no part of the Plan and are not to be considered in the construction of the Plan.

12.7Separability Of Provisions.

If any provision of this Plan shall be for any reason invalid or unenforceable, the remaining provisions shall nevertheless be carried into effect.

12.8Service Of Process.

The General Counsel of the Company shall constitute the Plan’s agent for service of process.

12.9Qualified Domestic Relations Order.

Notwithstanding anything in the Plan to the contrary, benefits may be distributed in accordance with the terms of an order that would constitute a qualified domestic relations order, within the meaning of Section 414(p) of the Code, with respect to the Basic Plan, as determined thereunder.

12.10No Trust.

Nothing contained in this Plan, and no action taken pursuant to its provisions, shall create, or be construed to create, a trust of any kind, or a fiduciary relationship between the Company or the Employer and the Participants, their beneficiaries hereunder or any other person.

12.11Section 409A Compliance.

The Plan is intended to meet the requirements of Section 409A of the Code (“Section 409A”) to the extent applicable (including short-term deferral rules promulgated thereunder) in order to avoid any adverse tax consequences resulting from any failure to comply with Section 409A and, as a result, the Plan (a) shall be deemed to be amended to the extent necessary to incorporate any provisions required to ensure such compliance (which provisions are hereby adopted, approved, consented to, ratified and incorporated herein by reference) and (b) shall be operated in a manner that will ensure such compliance. Any acts or omissions of Participants, beneficiaries and/or Plan officials under the Plan which fail to comply with any applicable requirements of this Section 13.11 shall be void and of no legal effect. For purposes of this Plan, the terms “termination of employment,” and “terminate,” “terminates” and “terminated” when used in the context of a Participant’s employment, mean “separation from service” with the Company and its affiliates (generally 50% common control with the Company), as defined in the Internal Revenue Service’s regulations under Section 409A (generally, a decrease in the performance of services to no more than 20% of the average for the preceding thirty-six (36)- month period, and disregarding leave of absences up to six (6) months where there is a reasonable expectation the Employee will return). Nothing in this Plan shall be interpreted to permit accelerated payment of nonqualified deferred compensation, as defined in Section 409A, or any other payment in violation of the requirements of Section 409A.

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IN WITNESS WHEREOF, the Company has caused this Plan to be executed by one of its duly authorized officers this

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EX-31.1

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 3, 2023

/s/ James C. Grech

James C. Grech

President and Chief Executive Officer 

EX-31.2

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”);

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 3, 2023

/s/ Mark A. Spurbeck

Mark A. Spurbeck

Executive Vice President and Chief Financial Officer 

EX-32.1

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, 2023 (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 3, 2023

/s/ James C. Grech 

James C. Grech

President and Chief Executive Officer 

EX-32.2

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:

(1)the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2023 (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 3, 2023

/s/ Mark A. Spurbeck

Mark A. Spurbeck

Executive Vice President and Chief Financial Officer 

EX-95

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, 2023, 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, 2023 were taken from the MSHA system as of July 31, 2023.

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, 2023

	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	3	—	—	—	—	—	5.5	—
Powder River Basin
North Antelope Rochelle	—	—	—	—	—	—	0.1	—
Rawhide	2	—	—	—	—	—	0.3	—
Other U.S. Thermal
Bear Run	—	—	—	—	—	—	0.3	1 (2)
El Segundo	2	—	—	—	—	—	—	—
Francisco Preparation Plant (Francisco Mine)	—	—	—	—	—	—	0.1	—
Francisco Underground	11	—	—	—	—	—	9.0	—
Gateway North	25	—	—	—	—	—	111.0	—
Kayenta	—	—	—	—	—	—	0.5	—
Twentymile (Foidel Creek Mine)	9	—	1	—	—	—	42.5	—

(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.

(2)On April 20, 2023, a contractor was fatally injured at the Bear Run Mine.

Six Months Ended June 30, 2023

	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	—	—	—	—	—	68.8	—
Powder River Basin
Caballo	1	—	—	—	—	—	6.4	—
North Antelope Rochelle	13	—	—	—	—	—	59.8	—
Rawhide	2	—	—	—	—	—	0.3	—
Other U.S. Thermal
Bear Run	2	—	—	—	—	—	7.2	1 (2)
El Segundo	3	—	—	—	—	—	3.3	—
Francisco Preparation Plant (Francisco Mine)	1	—	—	—	—	—	0.7	—
Francisco Underground	39	—	—	—	—	—	55.4	—
Gateway North	59	2	1	—	—	—	234.6	—
Kayenta	—	—	—	—	—	—	0.5	—
Somerville Central	1	—	—	—	—	—	0.1	—
Twentymile (Foidel Creek Mine)	13	—	1	—	—	—	70.1	—
Willow Lake Central Preparation Plant	1	—	—	—	—	—	1.2	—

(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.

(2)On April 20, 2023, a contractor was fatally injured at the Bear Run Mine.

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, 2023. 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, 2023	Legal Actions Resolved During the Three Months Ended June 30, 2023
	Number of Pending Legal Actions as of June 30, 2023	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	12	—	12	—	—	—	3	6
Powder River Basin
North Antelope Rochelle	—	—	—	—	—	—	—	3
Other U.S. Thermal
Bear Run	—	—	—	—	—	—	—	1
El Segundo	2	1	1	—	—	—	1	—
Francisco Underground	1	—	1	—	—	—	—	1
Gateway North	6	1	5	—	—	—	6	5
Twentymile (Foidel Creek)	1	—	1	—	—	—	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.

(2)Contests included a total of 1 appeal of judge's decisions or orders to the Commission as of June 30, 2023.

XML

Cover Page - shares shares in Millions	6 Months Ended
	Jun. 30, 2023	Jul. 28, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
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		132.8
Entity Central Index Key	0001064728
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Amendment Flag	false

XML

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Statement [Abstract]
Revenues	$ (1,268.8)	$ (1,321.9)	$ (2,632.8)	$ (2,013.3)
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	862.0	825.6	1,708.6	1,524.6
Depreciation, depletion and amortization	80.6	73.8	156.9	146.7
Asset retirement obligation expenses	15.5	12.7	30.9	27.7
Selling and administrative expenses	21.7	21.8	44.5	44.9
Restructuring charges	2.0	0.2	2.1	1.8
Other operating income:
Net gain on disposals	(5.2)	(12.8)	(7.1)	(17.7)
Asset impairment	0.0	0.0	2.0	0.0
Provision for NARM and Shoal Creek loss	33.7	0.0	33.7	0.0
Income from equity affiliates	(2.3)	(48.7)	(4.1)	(93.4)
Operating profit	260.8	449.3	665.3	378.7
Interest expense	13.3	37.6	31.7	77.0
Net loss on early debt extinguishment	2.0	2.3	8.8	25.8
Interest income	(23.1)	(0.9)	(36.2)	(1.4)
Net periodic benefit credit, excluding service cost	(9.7)	(12.3)	(19.4)	(24.5)
Income from continuing operations before income taxes	278.3	422.6	680.4	301.8
Income tax provision	74.2	11.3	192.2	10.3
Income from continuing operations, net of income taxes	204.1	411.3	488.2	291.5
Loss from discontinued operations, net of income taxes	(1.3)	(0.7)	(2.6)	(1.5)
Net income	202.8	410.6	485.6	290.0
Less: Net income attributable to noncontrolling interests	23.6	1.1	37.9	0.0
Net income attributable to common stockholders	$ 179.2	$ 409.5	$ 447.7	$ 290.0
Income from continuing operations:
Basic income per share	$ 1.27	$ 2.85	$ 3.14	$ 2.08
Diluted income per share	1.16	2.55	2.85	1.93
Net income attributable to common stockholders:
Basic income per share	1.26	2.84	3.12	2.07
Diluted income per share	$ 1.15	$ 2.54	$ 2.83	$ 1.93

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net income	$ 202.8	$ 410.6	$ 485.6	$ 290.0
Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)	(13.5)	(26.8)	(26.9)
Foreign currency translation adjustment	(0.4)	(3.4)	(0.6)	(1.5)
Other comprehensive loss, net of income taxes	(13.8)	(16.9)	(27.4)	(28.4)
Comprehensive income	189.0	393.7	458.2	261.6
Less: Net income attributable to noncontrolling interests	23.6	1.1	37.9	0.0
Comprehensive income attributable to common stockholders	$ 165.4	$ 392.6	$ 420.3	$ 261.6

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0

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CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current assets
Cash and cash equivalents	$ 1,080.5	$ 1,307.3
Accounts receivable, net of allowance for credit losses of $0.0 at June 30, 2023 and December 31, 2022	325.5	465.5
Inventories, net	312.9	296.1
Other current assets	244.3	303.6
Total current assets	1,963.2	2,372.5
Property, plant, equipment and mine development, net	2,819.5	2,865.0
Operating lease right-of-use assets	27.2	26.9
Restricted cash and collateral	925.4	187.4
Investments and other assets	73.8	84.3
Deferred income taxes	19.0	74.7
Total assets	5,828.1	5,610.8
Current liabilities
Current portion of long-term debt	13.0	13.2
Accounts payable and accrued expenses	892.1	905.5
Total current liabilities	905.1	918.7
Long-term debt, less current portion	321.5	320.6
Deferred income taxes	20.0	20.4
Asset retirement obligations	669.4	665.8
Accrued postretirement benefit costs	153.0	156.5
Operating lease liabilities, less current portion	11.7	11.0
Other noncurrent liabilities	224.1	223.0
Total liabilities	2,304.8	2,316.0
Stockholders’ equity
Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of June 30, 2023 and December 31, 2022	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, 2023 and December 31, 2022	0.0	0.0
Common Stock — $0.01 per share par value; 450.0 shares authorized, 188.6 shares issued and 135.9 shares outstanding as of June 30, 2023 and 187.1 shares issued and 143.9 shares outstanding as of December 31, 2022	1.9	1.9
Additional paid-in capital	3,979.4	3,975.9
Treasury stock, at cost — 52.7 and 43.2 common shares as of June 30, 2023 and December 31, 2022	(1,572.4)	(1,372.9)
Retained earnings	820.7	383.9
Accumulated other comprehensive income	215.1	242.5
Peabody Energy Corporation stockholders’ equity	3,444.7	3,231.3
Noncontrolling interests	78.6	63.5
Total stockholders’ equity	3,523.3	3,294.8
Total liabilities and stockholders’ equity	$ 5,828.1	$ 5,610.8
Treasury stock, shares (in shares)	52,700,000	43,200,000
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)	188,600,000	187,100,000
Common stock, shares outstanding (in shares)	135,900,000	143,900,000

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
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)	188,600,000	187,100,000
Common stock, shares outstanding (in shares)	135,900,000	143,900,000

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Cash Flows From Operating Activities
Net income	$ 202.8	$ 410.6	$ 485.6	$ 290.0
Loss from discontinued operations, net of income taxes	1.3	0.7	2.6	1.5
Income from continuing operations, net of income taxes	204.1	411.3	488.2	291.5
Adjustments to reconcile income from continuing operations, net of income taxes to net cash provided by operating activities:
Depreciation, depletion and amortization	80.6	73.8	156.9	146.7
Noncash interest expense, net			3.3	9.0
Deferred income taxes			65.0	(1.4)
Noncash share-based compensation			3.4	5.4
Asset impairment	0.0	0.0	2.0	0.0
Net gain on disposals	(5.2)	(12.8)	(7.1)	(17.7)
Noncash income from port and rail capacity assignment	(9.3)	0.0	(9.2)
Net loss on early debt extinguishment	2.0	2.3	8.8	25.8
Income from equity affiliates	(2.3)	(48.7)	(4.1)	(93.4)
Foreign currency option contracts			(0.6)	3.0
Changes in current assets and liabilities:
Accounts receivable			149.3	(179.9)
Inventories			(20.8)	(26.2)
Other current assets			43.4	(82.9)
Accounts payable and accrued expenses			(23.3)	(13.1)
Collateral arrangements			(116.9)	(28.2)
Asset retirement obligations			3.6	5.2
Workers’ compensation obligations			(0.7)	(1.6)
Postretirement benefit obligations			(30.4)	(32.2)
Pension obligations			0.7	(1.2)
Other, net			0.0	3.3
Net cash provided by continuing operations			745.2	12.1
Net cash used in discontinued operations			(5.5)	(2.7)
Net cash provided by operating activities			739.7	9.4
Cash Flows From Investing Activities
Additions to property, plant, equipment and mine development			(122.3)	(63.1)
Changes in accrued expenses related to capital expenditures			(5.4)	(9.7)
Proceeds from disposal of assets, net of receivables			12.0	23.4
Contributions to joint ventures			(370.8)	(276.0)
Distributions from joint ventures			365.8	280.8
Advances to related parties			(0.1)	(1.2)
Cash receipts from Middlemount Coal Pty Ltd and other related parties			1.7	143.9
Other, net			(0.9)	(3.6)
Net cash (used in) provided by investing activities			(120.0)	94.5
Cash Flows From Financing Activities
Proceeds from long-term debt			0.0	545.0
Repayments of long-term debt			(4.8)	(654.8)
Payment of debt issuance and other deferred financing costs			(0.3)	(20.7)
Proceeds from Issuance of Common Stock			0.0	222.0
Common stock repurchases			(173.0)	0.0
Repurchase of employee common stock relinquished for tax withholding			(13.7)	(2.6)
Dividends paid			(10.8)	0.0
Distributions to noncontrolling interests			(22.8)	(13.8)
Net cash (used in) provided by financing activities			(225.4)	75.1
Net change in cash, cash equivalents and restricted cash			394.3	179.0
Cash, cash equivalents and restricted cash at beginning of period (1)			1,417.6	954.3
Cash, cash equivalents and restricted cash at end of period (2)	1,811.9	1,133.3	1,811.9	1,133.3
Cash and cash equivalents	1,080.5		1,080.5
Restricted Cash	731.4		731.4
Provision for NARM and Shoal Creek loss	$ 33.7	$ 0.0	$ 33.7	$ 0.0

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY - USD ($) $ in Millions	Total	Common Stock	Additional paid-in capital	Retained earnings (Accumulated deficit)	Accumulated other comprehensive income	Noncontrolling interests	Treasury Stock, Common
Balance, beginning of period at Dec. 31, 2021		$ 1.8	$ 3,745.6	$ (913.2)	$ 297.9	$ 59.0	$ (1,370.3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based compensation for equity-classified awards			5.4
Common stock issuances, net of costs			221.9
Net income	$ 290.0			290.0		0.0
Dividends declared ($0.075, $0.000, $0.075, and $0.000 per share, respectively)				0.0
Repurchase of employee common stock relinquished for tax withholding	(2.6)						(2.6)
Postretirement plans (net of $0.0 tax provisions in each period)	(26.9)				(26.9)
Foreign currency translation adjustment	(1.5)				(1.5)
Distributions to noncontrolling interests						(13.8)
Common stock issuances, net of costs		0.1
Balance, end of period at Jun. 30, 2022	2,293.4	1.9	3,972.9	(623.2)	269.5	45.2	(1,372.9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock repurchases	0.0						0.0
Unsettled common stock repurchases							0.0
Dividend equivalent units on dividends declared			0.0
Sales and Excise Tax Payable							0.0
Balance, beginning of period at Mar. 31, 2022		1.9	3,969.5	(1,032.7)	286.4	44.1	(1,372.3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based compensation for equity-classified awards			3.4
Common stock issuances, net of costs			0.0
Net income	410.6			409.5		1.1
Dividends declared ($0.075, $0.000, $0.075, and $0.000 per share, respectively)				0.0
Repurchase of employee common stock relinquished for tax withholding							(0.6)
Postretirement plans (net of $0.0 tax provisions in each period)	(13.5)				(13.5)
Foreign currency translation adjustment	(3.4)				(3.4)
Distributions to noncontrolling interests						0.0
Common stock issuances, net of costs		0.0
Balance, end of period at Jun. 30, 2022	2,293.4	1.9	3,972.9	(623.2)	269.5	45.2	(1,372.9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock repurchases							0.0
Unsettled common stock repurchases							0.0
Dividend equivalent units on dividends declared			0.0
Sales and Excise Tax Payable							0.0
Balance, beginning of period at Dec. 31, 2022	3,294.8	1.9	3,975.9	383.9	242.5	63.5	(1,372.9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based compensation for equity-classified awards			3.4
Common stock issuances, net of costs			0.0
Net income	485.6			447.7		37.9
Dividends declared ($0.075, $0.000, $0.075, and $0.000 per share, respectively)				(10.9)
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)
Common stock issuances, net of costs		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]
Common stock repurchases	173.0						(173.0)
Unsettled common stock repurchases							(11.2)
Dividend equivalent units on dividends declared			0.1
Sales and Excise Tax Payable							(1.6)
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]
Share-based compensation for equity-classified awards			1.7
Common stock issuances, net of costs			0.0
Net income	202.8			179.2		23.6
Dividends declared ($0.075, $0.000, $0.075, and $0.000 per share, respectively)				(10.9)
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
Common stock issuances, net of costs		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]
Common stock repurchases							(173.0)
Unsettled common stock repurchases							(11.2)
Dividend equivalent units on dividends declared			$ 0.1
Sales and Excise Tax Payable							$ (1.6)

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY (Parenthetical) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0
Retained earnings (Accumulated deficit)
Dividends declared per share	$ 0.075	$ 0.000	$ 0.075	$ 0.000
Accumulated other comprehensive income
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 0.0	$ 0.0	$ 0.0	$ 0.0

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Basis of Presentation

6 Months Ended

Jun. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation

The 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, 2022. 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, 2022 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, 2023 are not necessarily indicative of the results that may be expected for future quarters or for the year ending December 31, 2023.

Although there are new accounting pronouncements issued by the Financial Accounting Standards Board that the Company will adopt, as applicable, the Company does not believe any of these accounting pronouncements will have a material impact on its unaudited condensed consolidated financial statements or disclosures.

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Revenue Recognition

6 Months Ended

Jun. 30, 2023

Revenue Recognition [Abstract]

Revenue Recognition

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, 2022, for the Company’s policies regarding “Revenue” and “Accounts receivable, net.”

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, 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

	Three Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	39.8	$	—	$	229.9	$	222.8	$	—	$	492.5
Export	314.9		—		—		1.0		—		315.9
Total thermal	354.7		—		229.9		223.8		—		808.4
Metallurgical coal
Export	—		533.3		—		—		—		533.3
Total metallurgical	—		533.3		—		—		—		533.3
Other (2)	0.2		0.5		(0.2)		1.1		(21.4)		(19.8)
Revenue	$	354.9	$	533.8	$	229.7	$	224.9	$	(21.4)	$	1,321.9

	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

	Six Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	80.2	$	—	$	481.4	$	422.7	$	—	$	984.3
Export	525.4		—		—		1.0		—		526.4
Total thermal	605.6		—		481.4		423.7		—		1,510.7
Metallurgical coal
Export	—		851.3		—		—		—		851.3
Total metallurgical	—		851.3		—		—		—		851.3
Other (2)	0.5		3.8		(0.5)		4.3		(356.8)		(348.7)
Revenue	$	606.1	$	855.1	$	480.9	$	428.0	$	(356.8)	$	2,013.3

(1)    Corporate and Other includes the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Unrealized gains (losses) on derivative contracts related to forecasted sales	$	40.3	$	(24.5)	$	159.0	$	(325.5)
Realized losses on derivative contracts related to forecasted sales	(30.3)		(122.6)		(80.9)		(190.6)
Revenue from physical sale of coal (3)	23.3		122.0		107.8		143.3
Trading revenue	0.1		0.3		0.1		10.4
Other (2)	3.8		3.4		25.6		5.6
Total Corporate and Other	$	37.2	$	(21.4)	$	211.6	$	(356.8)

(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 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, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Trade receivables, net	$	278.5	$	416.3
Miscellaneous receivables, net	47.0		49.2
Accounts receivable, net	$	325.5	$	465.5

None of the above receivables included allowances for credit losses at June 30, 2023 or December 31, 2022. No charges for credit losses were recognized during the three and six months ended June 30, 2023 or 2022.

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Inventories

6 Months Ended

Jun. 30, 2023

Inventory Disclosure [Abstract]

Inventories

Inventories

“Inventories, net” as of June 30, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Materials and supplies, net	$	152.0	$	130.8
Raw coal	94.2		98.3
Saleable coal	66.7		67.0
Inventories, net	$	312.9	$	296.1

Materials and supplies inventories, net presented above have been shown net of reserves of $8.5 million and $9.5 million as of June 30, 2023 and December 31, 2022.

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Equity Method Investments

6 Months Ended

Jun. 30, 2023

Equity Method Investment, Summarized Financial Information [Abstract]

Equity Method Investments

Equity Method Investments

The Company’s equity method investments include its joint venture interest 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 “Income from equity affiliates”:

					(Income) Loss from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2023		December 31, 2022		2023		2022		2023		2022
	(Dollars in millions)
Equity method investment related to Middlemount	$	33.1	$	27.1	$	(4.1)	$	(49.5)	$	(6.7)	$	(95.2)
Equity method investment related to R3	7.8		7.0		1.8		0.8		2.6		1.8
Total equity method investments	$	40.9	$	34.1	$	(2.3)	$	(48.7)	$	(4.1)	$	(93.4)

The Company received no cash payments from Middlemount during the six months ended June 30, 2023. Payments of $143.2 million were received from Middlemount during the six months ended June 30, 2022.

One of the Company’s Australian subsidiaries is party to an agreement to provide a revolving loan to Middlemount. The Company’s participation in the revolving loan will not, at any time, exceed its 50% equity interest of the revolving loan limit, which was $50 million Australian dollars at June 30, 2023. The revolving loan bears interest at 10% per annum and expires on December 31, 2023. There was no outstanding revolving loan at June 30, 2023 or December 31, 2022.

In March 2022, the Company entered into a joint venture with unrelated partners to form R3. R3 was formed 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 contributed $3.5 million and $2.5 million to R3 during the six months ended June 30, 2023 and 2022, respectively.

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Derivatives and Fair Value Measurements

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Derivatives and Fair Value Measurements

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, (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, (3) price risk and the variability of cash flows related to forecasted diesel fuel purchased for use in its operations and (4) interest rate risk on long-term debt. 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. The Company had no diesel fuel or interest rate derivatives in place as of June 30, 2023.

Foreign Currency Option Contracts

The Company has historically utilized currency forwards and options to hedge currency risk associated with anticipated Australian dollar expenditures. As of June 30, 2023, the Company held average rate options with an aggregate notional amount of $486.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending March 31, 2024. 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 $0.75 over the nine-month period ending March 31, 2024. As of June 30, 2023, the Company also held purchased collars with an aggregate notional amount of $514.0 million Australian dollars related to anticipated Australian dollar expenditures during the nine-month period ending March 31, 2024. The purchased collars have a floor and ceiling of approximately $0.60 and $0.75, 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, 2023, the Company had no coal derivative contracts related to its forecasted sales. Historically, such financial contracts have included futures, forwards and options. The Company classifies certain physical forward sales contracts as derivatives for which the normal purchase, normal sales exception does not apply.

During the three months ended June 30, 2023, the Company recorded a net unrealized mark-to-market gain of $40.3 million on financial coal derivative contracts, and no unrealized mark-to-market gains or losses on physical forward sales contracts. During the three months ended June 30, 2022, the Company recorded a net unrealized mark-to-market loss of $24.5 million on coal derivative contracts, which included approximately $40 million of unrealized mark-to-market losses on financial derivatives and approximately $15 million of unrealized mark-to-market gains on physical forward sales contracts.

During the six months ended June 30, 2023, the Company recorded a net unrealized mark-to-market gain of $159.0 million on financial coal derivative contracts, and no unrealized mark-to-market gains or losses on physical forward sales contracts. During the six months ended June 30, 2022, the Company recorded a net unrealized mark-to-market loss of $325.5 million on coal derivative contracts, which included approximately $306 million of unrealized mark-to-market losses on financial derivatives and approximately $20 million of unrealized mark-to-market losses on physical forward sales contracts.

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, 2023.

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. The fair value of derivatives reflected in the accompanying condensed consolidated balance sheets are set forth in the table below.

	June 30, 2023				December 31, 2022
	Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative
	(Dollars in millions)
Foreign currency option contracts	$	0.9	$	—	$	3.0	$	—
Derivative contracts related to forecasted sales	30.4		(15.4)		100.6		(310.3)
Financial trading contracts	—		(15.0)		11.7		—
Total derivatives	31.3		(30.4)		115.3		(310.3)
Effect of counterparty netting	(30.4)		30.4		(100.6)		100.6
Variation margin (received) posted	—		—		(11.7)		209.7
Net derivatives and variation margin as classified in the balance sheets	$	0.9	$	—	$	3.0	$	—

The Company generally posts or receives variation margin cash with its clearing broker on the majority of its financial derivatives as market values of the financial derivatives fluctuate. As of June 30, 2023, the Company had no margin cash posted. As of December 31, 2022, the Company had posted $255.5 million aggregate margin cash, consisting of $198.0 million variation margin cash and $57.5 million initial margin.

The net amount of asset derivatives, net of variation margin, is included in “Other current assets” and the net amount of liability derivatives, net of variation margin, is included in “Accounts payable and accrued expenses” in the accompanying condensed consolidated balance sheets. The amounts of initial margin are not included with the derivatives presented in the tabular disclosures above and are included in “Other current assets” in the accompanying condensed consolidated balance sheets.

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, 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
		Three Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain 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	$	(7.5)	$	(1.2)	$	(6.3)
Derivative contracts related to forecasted sales	Revenue	(147.1)		(122.6)		(24.5)
Financial trading contracts	Revenue	0.3		0.9		(0.6)
Total		$	(154.3)	$	(122.9)	$	(31.4)
		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
		Six Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized (loss) gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(2.2)	$	(3.0)
Derivative contracts related to forecasted sales	Revenue	(516.1)		(190.6)		(325.5)
Financial trading contracts	Revenue	10.4		0.2		10.2
Total		$	(510.9)	$	(192.6)	$	(318.3)

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.

The following tables set forth the hierarchy of the Company’s net asset (liability) positions for which fair value is measured on a recurring basis. Variation margin cash associated with the derivative balances is excluded from this table.

	June 30, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	0.9	$	—	$	0.9
Derivative contracts related to forecasted sales	—		15.0		—		15.0
Financial trading contracts	—		(15.0)		—		(15.0)
Equity securities	—		—		0.3		0.3
Total net assets	$	—	$	0.9	$	0.3	$	1.2
	December 31, 2022
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	3.0	$	—	$	3.0
Derivative contracts related to forecasted sales	—		(209.7)		—		(209.7)
Financial trading contracts	—		11.7		—		11.7
Equity securities	—		—		2.5		2.5
Total net (liabilities) assets	$	—	$	(195.0)	$	2.5	$	(192.5)

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 currently 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, 2023 and December 31, 2022:

•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- and variable-rate long-term debt relates to the potential reduction in the fair value and negative impact to future earnings, respectively, 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, 2023		December 31, 2022
	(Dollars in millions)
Total debt at par value	$	343.5	$	343.6
Less: Unamortized debt issuance costs	(9.0)		(9.8)
Net carrying amount	$	334.5	$	333.8
Estimated fair value	$	454.8	$	560.0

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.

Significant increases or decreases in the inputs in isolation could result in a significantly higher or lower fair value measurement. The unobservable inputs do not have a direct interrelationship; therefore, a change in one unobservable input would not necessarily correspond with a change in another unobservable input.

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, and will mark the investment to market as a Level 1 asset prospectively.

The Company had no transfers between Levels 1, 2 and 3 during the three and six months ended June 30, 2023 and 2022. The Company’s policy is to value all transfers between levels using the beginning of period valuation.

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Property, Plant, Equipment and Mine Development

6 Months Ended

Jun. 30, 2023

Property, Plant and Equipment [Abstract]

Property, Plant, Equipment and Mine Development

Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of June 30, 2023 and December 31, 2022 is set forth in the table below:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Land and coal interests	$	2,511.9	$	2,514.7
Buildings and improvements	628.8		594.2
Machinery and equipment	1,612.0		1,543.1
Less: Accumulated depreciation, depletion and amortization	(1,933.2)		(1,787.0)
Property, plant, equipment and mine development, net	$	2,819.5	$	2,865.0

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Income Taxes	6 Months Ended
	Jun. 30, 2023
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, 2023 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 $74.2 million and $11.3 million for the three months ended June 30, 2023 and 2022, respectively, included a tax provision of $0.3 million and a tax benefit of $3.5 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax provisions of $192.2 million and $10.3 million for the six months ended June 30, 2023 and 2022, respectively, included a tax provision of $0.7 million and a tax benefit of $1.9 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.

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Long-term Debt

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Long-term Debt

Long-term Debt 

The Company’s total indebtedness as of June 30, 2023 and December 31, 2022 consisted of the following:

Debt Instrument (defined below, as applicable)	June 30, 2023		December 31, 2022
	(Dollars in millions)
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0
Finance lease obligations	23.5		23.6
Less: Debt issuance costs	(9.0)		(9.8)
	334.5		333.8
Less: Current portion of long-term debt	13.0		13.2
Long-term debt	$	321.5	$	320.6

During 2022, the Company utilized various methods allowable or required under its then-existing debt agreements to retire all of its senior secured long-term debt, leaving only its unsecured 3.250% Convertible Senior Notes due 2028 (the 2028 Convertible Notes), which are further described below, and various finance lease obligations outstanding at December 31, 2022.

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.

The Company used the proceeds of the offering of the 2028 Convertible Notes and available cash to redeem $62.6 million of senior secured notes maturing in 2024 and $257.4 million of senior secured notes maturing in 2025, 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 and recognized a loss on early debt extinguishment of $23.0 million during the three months ended March 31, 2022.

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 bore interest from March 1, 2022 at a rate of 3.250% per year, payable semi-annually in arrears on March 1 and September 1 of each year, beginning on September 1, 2022.

The 2028 Convertible Notes’ indenture requires 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%. Under the applicable conversion rate formula, the $0.075 per share dividend declared on April 27, 2023 and paid on May 31, 2023 yielded a revised conversion rate of 50.5451 shares per $1,000 principal amount of 2028 Convertible Notes, which did not meet the 1% threshold to impact the existing conversion rate of 50.3816. The conversion rate may be impacted prospectively, based upon cumulative dividends paid.

During the first and second quarters of 2023, 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 2023, and will not be similarly convertible during the third quarter of 2023.

As of June 30, 2023, the if-converted value of the 2028 Convertible Notes exceeded the principal amount by $29.2 million.

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 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,
	2023		2022		2023		2022
	(Dollars in millions)
Indebtedness	$	5.3	$	24.0	$	11.7	$	49.9
Financial assurance instruments	8.0		13.6		20.0		27.1
Interest expense	$	13.3	$	37.6	$	31.7	$	77.0
Cash paid for interest	$	22.9	$	40.6	$	41.9	$	77.8
Non-cash interest expense	$	1.7	$	5.2	$	3.3	$	9.0

Covenant Compliance

The Company was compliant with all relevant covenants under its debt and other finance agreements at June 30, 2023. The April 2023 termination of the Company’s credit agreement and related letter of credit facility, as described in Note 11. “Financial Instruments and Other Guarantees,” eliminated the related compliance requirements as of March 31, 2023 and prospectively.

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Pension and Postretirement Benefit Costs

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Pension and Postretirement Benefit Costs

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 (credit) included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Interest cost on projected benefit obligation	$	7.4	$	5.4	$	14.8	$	10.7
Expected return on plan assets	(6.6)		(6.0)		(13.2)		(11.9)
Net periodic pension cost (credit)	$	0.8	$	(0.6)	$	1.6	$	(1.2)

Annual contributions to the qualified plans 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 (generally 80%). As of June 30, 2023, the Company’s qualified plans were expected to be at or above the Pension Protection Act thresholds. The Company is not required to make any contributions to its qualified pension plans in 2023 based on minimum funding requirements and does not expect to make any discretionary contributions in 2023 at this time.

In March 2022, Peabody Investments Corp. (PIC), a wholly-owned subsidiary of PEC, entered into a commitment agreement relating to the Peabody Investments Corp. Retirement Plan (the Peabody Plan) with The Prudential Insurance Company of America (Prudential) and Fiduciary Counselors Inc., as independent fiduciary to the Peabody Plan. Under the commitment agreement, the Peabody Plan purchased a buy-in group annuity contract (GAC) from Prudential for approximately $500 million and Prudential would reimburse the Peabody Plan for benefit payments to be made to the Peabody Plan’s participants. The benefit obligation was not transferred to Prudential and the Peabody Plan continued to administer and pay the retirement benefits of Peabody Plan participants and was reimbursed by Prudential for the payment of all benefits covered by the GAC. The purchase of the GAC was funded directly by the Peabody Plan’s assets. There was no impact on the monthly retirement benefits paid to Peabody Plan participants and no material impact on contributions for the Peabody Plan in 2022 or 2023 as a result of this transaction.

In May 2022, the Board of Directors of PIC approved the termination of the Peabody Plan effective July 31, 2022. In June 2022, the Peabody Plan’s participants were notified of the Peabody Plan termination and PIC filed an application with the Internal Revenue Service to request a determination as to the qualified status under §401(a) of the Internal Revenue Code of 1986 with respect to the amendment and termination of the Peabody Plan. In May 2023, PIC received a favorable determination from the Internal Revenue Service as to the Peabody Plan’s qualified status with respect to its plan termination.

In February 2023, as part of the Peabody Plan termination process, PIC announced a program to offer a voluntary lump-sum pension payout to certain active and deferred participants of the Peabody Plan which would fully settle the Peabody Plan’s obligation to them. The program provided participants with a limited-time opportunity to elect to receive a lump-sum settlement of their pension benefit or begin to receive their benefit in the form of a monthly annuity in May 2023.

During the six months ended June 30, 2023, the Company settled $21.9 million of its pension obligations for active and deferred participants in the Peabody Plan with an equal amount paid from plan assets.

As part of the completion of the standard Employee Retirement Income Security Act plan termination process for the Peabody Plan, on July 31, 2023, the GAC with Prudential was converted from a buy-in group annuity contract to a buy-out group annuity contract, irrevocably transferring the remaining benefit obligation and administration to Prudential. The Peabody Plan no longer administers or pays the retirement benefits of Peabody Plan participants. No cash contributions are expected to be required to complete the termination process for the Peabody Plan.

Net periodic postretirement benefit credit included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Service cost for benefits earned	$	0.2	$	0.2	$	0.3	$	0.4
Interest cost on accumulated postretirement benefit obligation	2.5		1.8		5.0		3.5
Expected return on plan assets	(0.2)		(0.2)		(0.3)		(0.4)
Amortization of prior service credit	(13.4)		(13.5)		(26.8)		(26.9)
Net periodic postretirement benefit credit	$	(10.9)	$	(11.7)	$	(21.8)	$	(23.4)

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 2023 and plans to utilize a portion of VEBA assets to make certain benefit payments.

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Earnings per Share (EPS)

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Earnings per Share (EPS)

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, 2023 and 2022 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.

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,
	2023		2022		2023		2022
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	180.5		410.2		450.3		291.5
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	179.2	$	409.5	$	447.7	$	290.0
Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.5		2.5		6.1		3.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	184.0		412.7		456.4		295.0
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	182.7	$	412.0	$	453.8	$	293.5
EPS denominator:
Weighted average shares outstanding — basic	142.3		144.0		143.4		140.1
Dilutive impact of share-based compensation awards	0.6		1.8		0.7		1.5
Dilutive impact of 2028 Convertible Notes	16.1		16.1		16.1		10.9
Weighted average shares outstanding — diluted	159.0		161.9		160.2		152.5
Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.27	$	2.85	$	3.14	$	2.08
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.01)
Net income attributable to common stockholders	$	1.26	$	2.84	$	3.12	$	2.07
Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.16	$	2.55	$	2.85	$	1.93
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		—
Net income attributable to common stockholders	$	1.15	$	2.54	$	2.83	$	1.93

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Financial Instruments and Other Guarantees

6 Months Ended

Jun. 30, 2023

Financial Instruments And Guarantees [Abstract]

Financial Instruments and Other Guarantees

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.

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

	June 30, 2023						December 31, 2022
	Reclamation Support		Other Support (1)		Total		Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	1,119.0	$	113.1	$	1,232.1	$	1,250.1	$	126.7	$	1,376.8
Letters of credit (2)	23.8		94.0		117.8		437.8		131.8		569.6
	1,142.8		207.1		1,349.9		1,687.9		258.5		1,946.4
Less: Letters of credit in support of surety bonds (3)	(23.8)		(5.9)		(29.7)		(431.7)		(37.2)		(468.9)
Obligations supported, net	$	1,119.0	$	201.2	$	1,320.2	$	1,256.2	$	221.3	$	1,477.5

(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 agreement, the Company was required to post collateral on a periodic basis through December 31, 2025. Prior to the April 2023 amendment, the Company had posted cumulative collateral of $557.8 million, primarily in the form of letters of credit.

Under the April 2023 amendment, the Company and 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 represented a negotiated increase from the uncapped cumulative collateral amount prior to the amendment and will vary prospectively as bonding levels increase or decrease. The amendment also removed restrictions on the payment of dividends and share repurchases, and extended the agreement through December 31, 2026. In order to maintain the new maximum collateral standstill, 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 $533.6 million at June 30, 2023. 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, which commenced for the second quarter of 2023. The Company granted second liens on $200.0 million of mining equipment under the original agreement, which remain in force under the April 2023 amendment.

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 credit agreement which, as amended, provided for $237.2 million of capacity for irrevocable standby letters of credit (LC Facility). All letters of credit that were outstanding under the LC Facility were cancelled upon its termination and, in certain cases, replaced by cash-collateralized letters of credit or letters of credit issued under the Company’s accounts receivable securitization program.

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 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.

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 secured overnight financing rate (SOFR). 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 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, 2023, the Company had no outstanding borrowings and $117.8 million of letters of credit outstanding under the Securitization Program, primarily in support of reclamation obligations. Availability under the Securitization Program, which is adjusted for certain ineligible receivables, was $34.8 million at June 30, 2023. The Company was not required to post cash collateral under the Securitization Program at June 30, 2023.

The Company incurred interest and fees associated with the Securitization Program of $0.8 million and $0.9 million during the three months ended June 30, 2023 and 2022, respectively, and $1.9 million and $1.8 million during the six months ended June 30, 2023 and 2022, respectively, which have been recorded as “Interest expense” in the accompanying unaudited condensed consolidated statements of operations.

Collateralized Letter of Credit Agreement

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, 2023, letters of credit of $168.2 million were outstanding under the agreement, which were collateralized by cash of $173.2 million.

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

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	558.2	$	—
Collateralized letters of credit funding (2)	173.2		110.3
	731.4		110.3
Other collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	194.0		33.6
LC Facility (3)	—		28.5
Deposit held on behalf of surety	—		15.0
	194.0		77.1
Restricted cash and collateral	$	925.4	$	187.4

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

(2)    Surety trust accounts and the funding for collateralized letters of credit 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.

(3)    Balance related to the Company’s mandatory repurchase of $30.0 million priority lien obligations under the LC Facility during 2022 at approximately 95%. The Company received approximately $30.0 million upon termination of the LC Facility on April 14, 2023

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of June 30, 2023, purchase commitments for capital expenditures were $100.8 million, all of which is obligated within the next two years, with $94.1 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, 2022.

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. Over the past few years, there has been significantly high rainfall in New South Wales, including unprecedented rain totals at the Metropolitan Mine site. While stormwater collected at the mine site is managed through two sedimentation dams, at times the heavy rainfall has presented challenges with managing the significant volumes of stormwater, as the surface water management infrastructure has not had sufficient capacity. As a result, on multiple occasions throughout 2021 and 2022 stormwater has been discharged from the mine site. Metropolitan Collieries Pty Ltd (MCPL), a wholly-owned subsidiary of PEC, removed accumulated material from the sedimentation dams to restore full site stormwater capacity by December 31, 2022 and has identified and is implementing additional controls for the management of sediment moving forward. Despite the measures undertaken by MCPL to manage and improve the situation, the Environment Protection Authority is currently undertaking an investigation in relation to the discharges of sediment laden water from the mine site and whether there are potential offenses against the environmental protection legislation arising from the stormwater discharges from the site. The Environmental Protection Authority has also completed a review of MCPL’s environmental protection license and has implemented some additional compliance conditions.

Puerto Rico Climate Change Lawsuit. On November 22, 2022, the Municipalities of Puerto Rico filed a class action complaint for damages against several major energy fuel producers, including Peabody Energy. This lawsuit represents the latest in a series of lawsuits that have been brought in both state and federal court around the United States, generally seeking to impose liability on the energy fuel producers for the effects allegedly caused by climate change. Many of these lawsuits have been brought on behalf of governmental entities (counties, cities, and towns) by plaintiff law firms on a contingent fee arrangement. The causes of action in the Puerto Rico lawsuit include public and private nuisance, liability for failure to warn, consumer fraud, antitrust and claims under the Racketeer Influenced and Corrupt Organizations Act. On April 21, 2023, the plaintiffs filed a Notice of Voluntary Dismissal dismissing all claims against the Company without prejudice.

Oregon Climate Change Lawsuit. On July 20, 2023, Peabody Energy was served with a summons issued on behalf of Multnomah County, Oregon. The complaint seeks 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, include a failure to warn, false or misleading advertisement and public nuisance. The Company will defend the claim and will continue to assert all applicable defenses available in regards to these claims.

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.

Claims, Litigation and Settlements Relating to Indemnities or Historical Operations

Patriot-Related Matters. Included in the Company’s discontinued operations are the previously divested legacy operations of Patriot Coal Corporation and certain of its wholly-owned subsidiaries (Patriot). In 2012, Patriot filed voluntary petitions for relief under Chapter 11 of Title 11 of the U.S. Code (the Bankruptcy Code). In 2013, the Company entered into a definitive settlement agreement (2013 Agreement) with Patriot and the United Mine Workers of America, on behalf of itself, its represented Patriot employees and its represented Patriot retirees, to resolve all then-disputed issues related to Patriot’s bankruptcy. In May 2015, Patriot again filed voluntary petitions for relief under the Bankruptcy Code and subsequently initiated a process to sell substantially all of its assets to qualified bidders. On October 9, 2015, Patriot’s bankruptcy court entered an order confirming Patriot’s plan of reorganization, which provided, among other things, for the sale of substantially all of Patriot’s assets to two different buyers.

Patriot had federal and state black lung occupational disease liabilities related to workers employed in periods prior to Patriot’s spin-off from the Company in 2007. Upon spin-off, Patriot indemnified the Company against any claim relating to these liabilities, which amounted to approximately $150 million at that time. The indemnification included any claim made by the U.S. Department of Labor (DOL) against the Company with respect to these obligations as a potentially liable operator under the Federal Coal Mine Health and Safety Act of 1969. The 2013 Agreement included Patriot’s affirmance of indemnities provided in the spin-off agreements, including the indemnity relating to such black lung liabilities; however, Patriot rejected this indemnity in its May 2015 bankruptcy.

By statute, the Company had secondary liability for the black lung liabilities related to Patriot’s workers employed by former subsidiaries of the Company. The Company’s accounting for the black lung liabilities related to Patriot is based on an interpretation of applicable statutes. Management believes that inconsistencies exist among the applicable statutes, regulations promulgated under those statutes and the DOL’s interpretative guidance. The Company has sought clarification from the DOL regarding these inconsistencies and has challenged the DOL’s position in individual black lung claims. The amount of these liabilities could be reduced in the future. Whether the Company will ultimately be required to fund certain of those obligations in the future as a result of Patriot’s May 2015 bankruptcy remains uncertain. The amount of the liability, which was determined on an actuarial basis based on the best information available to the Company, was $80.0 million and $82.3 million at June 30, 2023 and December 31, 2022, respectively. The liability, which is classified as discontinued operations, is included in the Company’s condensed consolidated balance sheets within “Accounts payable and accrued expenses” and “Other noncurrent liabilities.” While the Company has recorded a liability, it intends to review each claim on a case-by-case basis and contest liability estimates as appropriate. The amount of the Company’s recorded liability reflects only Patriot workers employed by former subsidiaries of the Company that are presently retired, disabled or otherwise not actively employed. The Company cannot reliably estimate the potential liabilities for Patriot’s workers employed by former subsidiaries of the Company that are presently active in the workforce because of the potential for such workers to continue to work for another coal operator that is a going concern.

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Segment Information

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Segment Information

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 chief operating decision maker, 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,
	2023		2022		2023		2022
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	399.5	$	354.9	$	746.0	$	606.1
Seaborne Metallurgical	372.5		533.8		660.9		855.1
Powder River Basin	259.7		229.7		565.0		480.9
Other U.S. Thermal	199.9		224.9		449.3		428.0
Corporate and Other	37.2		(21.4)		211.6		(356.8)
Total	$	1,268.8	$	1,321.9	$	2,632.8	$	2,013.3
Adjusted EBITDA:
Seaborne Thermal	$	197.5	$	176.8	$	361.5	$	267.3
Seaborne Metallurgical	102.5		299.7		193.3		480.7
Powder River Basin	26.2		(2.0)		62.0		5.6
Other U.S. Thermal	51.9		61.9		116.1		111.9
Corporate and Other	(19.9)		41.4		15.9		39.8
Total	$	358.2	$	577.8	$	748.8	$	905.3

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,
	2023		2022		2023		2022
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Depreciation, depletion and amortization	80.6		73.8		156.9		146.7
Asset retirement obligation expenses	15.5		12.7		30.9		27.7
Restructuring charges	2.0		0.2		2.1		1.8
Asset impairment	—		—		2.0		—
Provision for NARM and Shoal Creek loss	33.7		—		33.7		—
Changes in amortization of basis difference related to equity affiliates	(0.4)		(0.6)		(0.7)		(1.2)
Interest expense	13.3		37.6		31.7		77.0
Net loss on early debt extinguishment	2.0		2.3		8.8		25.8
Interest income	(23.1)		(0.9)		(36.2)		(1.4)
Unrealized (gains) losses on derivative contracts related to forecasted sales	(40.3)		24.5		(159.0)		325.5
Unrealized (gains) losses on foreign currency option contracts	(2.8)		6.3		(0.6)		3.0
Take-or-pay contract-based intangible recognition	(0.6)		(0.7)		(1.2)		(1.4)
Income tax provision	74.2		11.3		192.2		10.3
Adjusted EBITDA	$	358.2	$	577.8	$	748.8	$	905.3

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Other Events

6 Months Ended

Jun. 30, 2023

Other Events [Abstract]

Other Events

Other Events

Share Repurchases

During the three months ended June 30, 2023, the Company repurchased approximately 8.9 million shares of its common stock for $184.2 million, including commission fees. Of this amount, $11.2 million related to repurchases which settled subsequent to June 30, 2023. The Company recognized excise taxes of $1.6 million related to the repurchases, which were unpaid at June 30, 2023. The Company includes commission fees and excise taxes, as incurred, with the cost of treasury stock. Subsequent to June 30, 2023, the Company repurchased an additional 3.1 million shares for $67.0 million.

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. The provision includes $4.0 million for materials and supplies inventories and $1.0 million for buildings and equipment. This provision represents the best estimate of potential loss based on the assessments made to date. The Company continues to assess the loss and anticipates that incremental repair costs will be recorded in future periods.

Shoal Creek Incident

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. Development coal production has been resumed in a new 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. The provision includes $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.

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 North Goonyella 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 is 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 and had a discounted receivable of $9.3 million included in “Accounts receivable, net” as of June 30, 2023.

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pay vs Performance Disclosure
Net Income (Loss)	$ 179.2	$ 409.5	$ 447.7	$ 290.0

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Insider Trading Arrangements

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2023

Trading Arrangements, by Individual

Material Terms of Trading Arrangement

Securities Trading Plans of Directors and Executive Officers

During the three months ended June 30, 2023, none of Peabody’s directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as those terms are defined in Item 408 of Regulation S-K.

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

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Derivative Instruments and Hedging Activities (Policies)	6 Months Ended
	Jun. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Corporate Hedging - Coal Trading	Significant increases or decreases in the inputs in isolation could result in a significantly higher or lower fair value measurement. The unobservable inputs do not have a direct interrelationship; therefore, a change in one unobservable input would not necessarily correspond with a change in another unobservable input.
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, (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, (3) price risk and the variability of cash flows related to forecasted diesel fuel purchased for use in its operations and (4) interest rate risk on long-term debt. 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. The Company had no diesel fuel or interest rate derivatives in place as of June 30, 2023.

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2023

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, 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

	Three Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	39.8	$	—	$	229.9	$	222.8	$	—	$	492.5
Export	314.9		—		—		1.0		—		315.9
Total thermal	354.7		—		229.9		223.8		—		808.4
Metallurgical coal
Export	—		533.3		—		—		—		533.3
Total metallurgical	—		533.3		—		—		—		533.3
Other (2)	0.2		0.5		(0.2)		1.1		(21.4)		(19.8)
Revenue	$	354.9	$	533.8	$	229.7	$	224.9	$	(21.4)	$	1,321.9

	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

	Six Months Ended June 30, 2022
	Seaborne Thermal		Seaborne Metallurgical		Powder River Basin		Other U.S. Thermal		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	80.2	$	—	$	481.4	$	422.7	$	—	$	984.3
Export	525.4		—		—		1.0		—		526.4
Total thermal	605.6		—		481.4		423.7		—		1,510.7
Metallurgical coal
Export	—		851.3		—		—		—		851.3
Total metallurgical	—		851.3		—		—		—		851.3
Other (2)	0.5		3.8		(0.5)		4.3		(356.8)		(348.7)
Revenue	$	606.1	$	855.1	$	480.9	$	428.0	$	(356.8)	$	2,013.3

(1)    Corporate and Other includes the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Unrealized gains (losses) on derivative contracts related to forecasted sales	$	40.3	$	(24.5)	$	159.0	$	(325.5)
Realized losses on derivative contracts related to forecasted sales	(30.3)		(122.6)		(80.9)		(190.6)
Revenue from physical sale of coal (3)	23.3		122.0		107.8		143.3
Trading revenue	0.1		0.3		0.1		10.4
Other (2)	3.8		3.4		25.6		5.6
Total Corporate and Other	$	37.2	$	(21.4)	$	211.6	$	(356.8)

(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 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.

Schedule of Accounts Receivable

“Accounts receivable, net” at June 30, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Trade receivables, net	$	278.5	$	416.3
Miscellaneous receivables, net	47.0		49.2
Accounts receivable, net	$	325.5	$	465.5

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Inventories (Tables)

6 Months Ended

Jun. 30, 2023

Inventory Disclosure [Abstract]

Schedule of Inventories

Inventories, net” as of June 30, 2023 and December 31, 2022 consisted of the following:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Materials and supplies, net	$	152.0	$	130.8
Raw coal	94.2		98.3
Saleable coal	66.7		67.0
Inventories, net	$	312.9	$	296.1

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

6 Months Ended

Jun. 30, 2023

Equity Method Investments and Joint Ventures [Abstract]

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 “Income from equity affiliates”:

					(Income) Loss from Equity Affiliates
	Book Value at				Three Months Ended June 30,				Six Months Ended June 30,
	June 30, 2023		December 31, 2022		2023		2022		2023		2022
	(Dollars in millions)
Equity method investment related to Middlemount	$	33.1	$	27.1	$	(4.1)	$	(49.5)	$	(6.7)	$	(95.2)
Equity method investment related to R3	7.8		7.0		1.8		0.8		2.6		1.8
Total equity method investments	$	40.9	$	34.1	$	(2.3)	$	(48.7)	$	(4.1)	$	(93.4)

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Derivatives and Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping

The fair value of derivatives reflected in the accompanying condensed consolidated balance sheets are set forth in the table below.

	June 30, 2023				December 31, 2022
	Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative
	(Dollars in millions)
Foreign currency option contracts	$	0.9	$	—	$	3.0	$	—
Derivative contracts related to forecasted sales	30.4		(15.4)		100.6		(310.3)
Financial trading contracts	—		(15.0)		11.7		—
Total derivatives	31.3		(30.4)		115.3		(310.3)
Effect of counterparty netting	(30.4)		30.4		(100.6)		100.6
Variation margin (received) posted	—		—		(11.7)		209.7
Net derivatives and variation margin as classified in the balance sheets	$	0.9	$	—	$	3.0	$	—

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, 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
		Three Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain 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	$	(7.5)	$	(1.2)	$	(6.3)
Derivative contracts related to forecasted sales	Revenue	(147.1)		(122.6)		(24.5)
Financial trading contracts	Revenue	0.3		0.9		(0.6)
Total		$	(154.3)	$	(122.9)	$	(31.4)
		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
		Six Months Ended June 30, 2022
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized (loss) gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.2)	$	(2.2)	$	(3.0)
Derivative contracts related to forecasted sales	Revenue	(516.1)		(190.6)		(325.5)
Financial trading contracts	Revenue	10.4		0.2		10.2
Total		$	(510.9)	$	(192.6)	$	(318.3)

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

The following tables set forth the hierarchy of the Company’s net asset (liability) positions for which fair value is measured on a recurring basis. Variation margin cash associated with the derivative balances is excluded from this table.

	June 30, 2023
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	0.9	$	—	$	0.9
Derivative contracts related to forecasted sales	—		15.0		—		15.0
Financial trading contracts	—		(15.0)		—		(15.0)
Equity securities	—		—		0.3		0.3
Total net assets	$	—	$	0.9	$	0.3	$	1.2
	December 31, 2022
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	3.0	$	—	$	3.0
Derivative contracts related to forecasted sales	—		(209.7)		—		(209.7)
Financial trading contracts	—		11.7		—		11.7
Equity securities	—		—		2.5		2.5
Total net (liabilities) assets	$	—	$	(195.0)	$	2.5	$	(192.5)

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, 2023		December 31, 2022
	(Dollars in millions)
Total debt at par value	$	343.5	$	343.6
Less: Unamortized debt issuance costs	(9.0)		(9.8)
Net carrying amount	$	334.5	$	333.8
Estimated fair value	$	454.8	$	560.0

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Property, Plant, Equipment and Mine Development (Tables)

6 Months Ended

Jun. 30, 2023

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, 2023 and December 31, 2022 is set forth in the table below:

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Land and coal interests	$	2,511.9	$	2,514.7
Buildings and improvements	628.8		594.2
Machinery and equipment	1,612.0		1,543.1
Less: Accumulated depreciation, depletion and amortization	(1,933.2)		(1,787.0)
Property, plant, equipment and mine development, net	$	2,819.5	$	2,865.0

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Long-term Debt (Tables)

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

The Company’s total indebtedness as of June 30, 2023 and December 31, 2022 consisted of the following:

Debt Instrument (defined below, as applicable)	June 30, 2023		December 31, 2022
	(Dollars in millions)
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	$	320.0	$	320.0
Finance lease obligations	23.5		23.6
Less: Debt issuance costs	(9.0)		(9.8)
	334.5		333.8
Less: Current portion of long-term debt	13.0		13.2
Long-term debt	$	321.5	$	320.6

Schedule of Interest Charges

Additionally, the table sets forth the amount of cash paid for 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,
	2023		2022		2023		2022
	(Dollars in millions)
Indebtedness	$	5.3	$	24.0	$	11.7	$	49.9
Financial assurance instruments	8.0		13.6		20.0		27.1
Interest expense	$	13.3	$	37.6	$	31.7	$	77.0
Cash paid for interest	$	22.9	$	40.6	$	41.9	$	77.8
Non-cash interest expense	$	1.7	$	5.2	$	3.3	$	9.0

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Pension and Postretirement Benefit Costs (Tables)

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs

Net periodic pension cost (credit) included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Interest cost on projected benefit obligation	$	7.4	$	5.4	$	14.8	$	10.7
Expected return on plan assets	(6.6)		(6.0)		(13.2)		(11.9)
Net periodic pension cost (credit)	$	0.8	$	(0.6)	$	1.6	$	(1.2)

Net periodic postretirement benefit credit included the following components:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Service cost for benefits earned	$	0.2	$	0.2	$	0.3	$	0.4
Interest cost on accumulated postretirement benefit obligation	2.5		1.8		5.0		3.5
Expected return on plan assets	(0.2)		(0.2)		(0.3)		(0.4)
Amortization of prior service credit	(13.4)		(13.5)		(26.8)		(26.9)
Net periodic postretirement benefit credit	$	(10.9)	$	(11.7)	$	(21.8)	$	(23.4)

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Earnings per Share (EPS) (Tables)

6 Months Ended

Jun. 30, 2023

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,
	2023		2022		2023		2022
	(In millions, except per share data)
Basic EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	180.5		410.2		450.3		291.5
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	179.2	$	409.5	$	447.7	$	290.0
Diluted EPS numerator:
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.5		2.5		6.1		3.5
Less: Net income attributable to noncontrolling interests	23.6		1.1		37.9		—
Income from continuing operations attributable to common stockholders	184.0		412.7		456.4		295.0
Loss from discontinued operations, net of income taxes	(1.3)		(0.7)		(2.6)		(1.5)
Net income attributable to common stockholders	$	182.7	$	412.0	$	453.8	$	293.5
EPS denominator:
Weighted average shares outstanding — basic	142.3		144.0		143.4		140.1
Dilutive impact of share-based compensation awards	0.6		1.8		0.7		1.5
Dilutive impact of 2028 Convertible Notes	16.1		16.1		16.1		10.9
Weighted average shares outstanding — diluted	159.0		161.9		160.2		152.5
Basic EPS attributable to common stockholders:
Income from continuing operations	$	1.27	$	2.85	$	3.14	$	2.08
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		(0.01)
Net income attributable to common stockholders	$	1.26	$	2.84	$	3.12	$	2.07
Diluted EPS attributable to common stockholders:
Income from continuing operations	$	1.16	$	2.55	$	2.85	$	1.93
Loss from discontinued operations	(0.01)		(0.01)		(0.02)		—
Net income attributable to common stockholders	$	1.15	$	2.54	$	2.83	$	1.93

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Guarantees (Tables)

3 Months Ended

Jun. 30, 2023

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, 2023						December 31, 2022
	Reclamation Support		Other Support (1)		Total		Reclamation Support		Other Support (1)		Total
	(Dollars in millions)
Surety bonds	$	1,119.0	$	113.1	$	1,232.1	$	1,250.1	$	126.7	$	1,376.8
Letters of credit (2)	23.8		94.0		117.8		437.8		131.8		569.6
	1,142.8		207.1		1,349.9		1,687.9		258.5		1,946.4
Less: Letters of credit in support of surety bonds (3)	(23.8)		(5.9)		(29.7)		(431.7)		(37.2)		(468.9)
Obligations supported, net	$	1,119.0	$	201.2	$	1,320.2	$	1,256.2	$	221.3	$	1,477.5

(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.

Restricted Cash and Collateral

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

	June 30, 2023		December 31, 2022
	(Dollars in millions)
Restricted cash (1)
Surety trust accounts (2)	$	558.2	$	—
Collateralized letters of credit funding (2)	173.2		110.3
	731.4		110.3
Other collateral (1)
Deposits with regulatory authorities for reclamation and other obligations	194.0		33.6
LC Facility (3)	—		28.5
Deposit held on behalf of surety	—		15.0
	194.0		77.1
Restricted cash and collateral	$	925.4	$	187.4

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

(2)    Surety trust accounts and the funding for collateralized letters of credit 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.

(3)    Balance related to the Company’s mandatory repurchase of $30.0 million priority lien obligations under the LC Facility during 2022 at approximately 95%. The Company received approximately $30.0 million upon termination of the LC Facility on April 14, 2023

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Reportable Segment Results

Reportable segment results were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(Dollars in millions)
Revenue:
Seaborne Thermal	$	399.5	$	354.9	$	746.0	$	606.1
Seaborne Metallurgical	372.5		533.8		660.9		855.1
Powder River Basin	259.7		229.7		565.0		480.9
Other U.S. Thermal	199.9		224.9		449.3		428.0
Corporate and Other	37.2		(21.4)		211.6		(356.8)
Total	$	1,268.8	$	1,321.9	$	2,632.8	$	2,013.3
Adjusted EBITDA:
Seaborne Thermal	$	197.5	$	176.8	$	361.5	$	267.3
Seaborne Metallurgical	102.5		299.7		193.3		480.7
Powder River Basin	26.2		(2.0)		62.0		5.6
Other U.S. Thermal	51.9		61.9		116.1		111.9
Corporate and Other	(19.9)		41.4		15.9		39.8
Total	$	358.2	$	577.8	$	748.8	$	905.3

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,
	2023		2022		2023		2022
	(Dollars in millions)
Income from continuing operations, net of income taxes	$	204.1	$	411.3	$	488.2	$	291.5
Depreciation, depletion and amortization	80.6		73.8		156.9		146.7
Asset retirement obligation expenses	15.5		12.7		30.9		27.7
Restructuring charges	2.0		0.2		2.1		1.8
Asset impairment	—		—		2.0		—
Provision for NARM and Shoal Creek loss	33.7		—		33.7		—
Changes in amortization of basis difference related to equity affiliates	(0.4)		(0.6)		(0.7)		(1.2)
Interest expense	13.3		37.6		31.7		77.0
Net loss on early debt extinguishment	2.0		2.3		8.8		25.8
Interest income	(23.1)		(0.9)		(36.2)		(1.4)
Unrealized (gains) losses on derivative contracts related to forecasted sales	(40.3)		24.5		(159.0)		325.5
Unrealized (gains) losses on foreign currency option contracts	(2.8)		6.3		(0.6)		3.0
Take-or-pay contract-based intangible recognition	(0.6)		(0.7)		(1.2)		(1.4)
Income tax provision	74.2		11.3		192.2		10.3
Adjusted EBITDA	$	358.2	$	577.8	$	748.8	$	905.3

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Revenue Recognition - Revenue by Product Type and Market (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Line Items]
Revenues	$ 1,268.8	$ 1,321.9	$ 2,632.8	$ 2,013.3
Other Income	3.8	3.4	25.6	5.6
Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	29.3	(31.4)	128.5	(318.3)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(19.3)	(122.9)	(55.5)	(192.6)
Derivative, Gain (Loss) on Derivative, Net	10.0	(154.3)	73.0	(510.9)
Derivative contracts related to forecasted sales | Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	40.3	(24.5)	159.0	(325.5)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(30.3)	(122.6)	(80.9)	(190.6)
Derivative, Gain (Loss) on Derivative, Net	10.0	(147.1)	78.1	(516.1)
Financial trading contracts | Designated as Hedging Instrument
Disaggregation of Revenue [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	(13.8)	(0.6)	(31.1)	10.2
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	13.9	0.9	31.2	0.2
Derivative, Gain (Loss) on Derivative, Net	0.1	0.3	0.1	10.4
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	40.3	(24.5)	159.0	(325.5)
Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	857.4	808.4	1,756.6	1,510.7
Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	371.6	533.3	658.8	851.3
Other (2)
Disaggregation of Revenue [Line Items]
Revenues	39.8	(19.8)	217.4	(348.7)
Domestic | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	489.9	492.5	1,080.3	984.3
Export | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	367.5	315.9	676.3	526.4
Export | Metallurgical coal
Disaggregation of Revenue [Line Items]
Revenues	371.6	533.3	658.8	851.3
Seaborne Thermal
Disaggregation of Revenue [Line Items]
Revenues	399.5	354.9	746.0	606.1
Seaborne Thermal | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	399.4	354.7	745.7	605.6
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	0.1	0.2	0.3	0.5
Seaborne Thermal | Domestic | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	31.9	39.8	69.4	80.2
Seaborne Thermal | Export | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	367.5	314.9	676.3	525.4
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	372.5	533.8	660.9	855.1
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	371.6	533.3	658.8	851.3
Seaborne Metallurgical | Other (2)
Disaggregation of Revenue [Line Items]
Revenues	0.9	0.5	2.1	3.8
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	371.6	533.3	658.8	851.3
Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	259.7	229.7	565.0	480.9
Powder River Basin | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	259.8	229.9	564.8	481.4
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	(0.1)	(0.2)	0.2	(0.5)
Powder River Basin | Domestic | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	259.8	229.9	564.8	481.4
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	199.9	224.9	449.3	428.0
Other U.S. Thermal | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	198.2	223.8	446.1	423.7
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	1.1	3.2	4.3
Other U.S. Thermal | Domestic | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	198.2	222.8	446.1	422.7
Other U.S. Thermal | Export | Thermal coal
Disaggregation of Revenue [Line Items]
Revenues	0.0	1.0	0.0	1.0
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	37.2	(21.4)	211.6	(356.8)
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	23.3	122.0	107.8	143.3
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	37.2	(21.4)	211.6	(356.8)
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

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Revenue Recognition - Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Revenue Recognition [Abstract]
Trade receivables, net	$ 278.5	$ 416.3
Miscellaneous receivables, net	47.0	49.2
Accounts receivable, net	$ 325.5	$ 465.5

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Revenue Recognition - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Revenue Recognition [Abstract]
Accounts receivable, allowance for credit loss	$ 0		$ 0		$ 0
Accounts receivable, credit loss expense (reversal)	$ 0	$ 0	$ 0	$ 0

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Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Inventory [Line Items]
Materials and supplies, net	$ 152.0	$ 130.8
Raw coal	94.2	98.3
Saleable coal	66.7	67.0
Inventories, net	$ 312.9	$ 296.1

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Inventories Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Material and supplies
Inventory [Line Items]
inventory reserves	$ 8.5	$ 9.5

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Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 40.9		$ 40.9		$ 34.1
Income (Loss) from Equity Method Investments	(2.3)	$ (48.7)	(4.1)	$ (93.4)
Middlemount Mine
Schedule of Equity Method Investments [Line Items]
Equity method investments	33.1		33.1		27.1
Income (Loss) from Equity Method Investments	4.1	49.5	6.7	95.2
R3 Renewables
Schedule of Equity Method Investments [Line Items]
Equity method investments	7.8		7.8		$ 7.0
Income (Loss) from Equity Method Investments	$ (1.8)	$ (0.8)	$ (2.6)	$ (1.8)

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Equity Method Investments Narrative (Details) $ in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 AUD ($)	Dec. 31, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Revolving Loans	$ 0.0			$ 0.0
R3 Renewables
Schedule of Equity Method Investments [Line Items]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	$ 3.5	$ 2.5
Middlemount Mine
Schedule of Equity Method Investments [Line Items]
Financing receivable, stated interest rate (in percent)	10.00%
Revolving loan limit			$ 50.0
Equity interest percentage of revolving loans limit	50.00%		50.00%
Cash receipts from Middlemount Coal Pty Ltd and other related parties	$ 0.0	$ 143.2

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Derivatives and Fair Value Measurements - Narrative (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023 USD ($) $ / $	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) $ / $	Jun. 30, 2022 USD ($)	Jun. 30, 2023 AUD ($) $ / $	Dec. 31, 2022 USD ($)
Derivatives, Fair Value [Line Items]
Unobservable Measurement Input, Uncertainty, Description			10
Asset impairment	$ 0.0	$ 0.0	$ 2.0	$ 0.0
Fair Value, Inputs, Level 1, 2 and 3
Derivatives, Fair Value [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0	0.0	0.0
Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Variation margin (received) posted	0.0		0.0			$ (209.7)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	29.3	(31.4)	128.5	(318.3)
Foreign currency option contracts
Derivatives, Fair Value [Line Items]
Notional amount	$ 514.0		$ 514.0		$ 486,000,000
Derivative, Floor Price					0.60
Derivative, Cap Price					0.75
Foreign currency option contracts | Minimum
Derivatives, Fair Value [Line Items]
Derivative, exchange rate cap (in dollars per share) | $ / $	0.70		0.70		0.70
Foreign currency option contracts | Maximum
Derivatives, Fair Value [Line Items]
Derivative, exchange rate cap (in dollars per share) | $ / $	0.75		0.75		0.75
Foreign currency option contracts | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	$ 2.8	(6.3)	$ 0.6	(3.0)
Financial trading contracts | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	(13.8)	(0.6)	(31.1)	10.2
Diesel Fuel Hedge Contracts
Derivatives, Fair Value [Line Items]
Notional amount					$ 0
Coal Contract and Physical commodity purchase / sale contracts | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	40.3	(24.5)	159.0	(325.5)
Gain (Loss) on Derivative Instruments | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		40.0		306.0
Forward Contracts | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax		15.0		20.0
Derivative contracts related to forecasted sales | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	40.3	$ (24.5)	159.0	$ (325.5)
Variation Margin Cash | Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Variation margin (received) posted						198.0
Total Margin Posted
Derivatives, Fair Value [Line Items]
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset	$ 0.0		$ 0.0			255.5
Initial Margin Posted
Derivatives, Fair Value [Line Items]
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset						$ 57.5

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Derivatives and Fair Value Measurements - Derivatives by Balance Sheet Classification (Details) - Designated as Hedging Instrument - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Asset Derivative
Derivative Asset, Fair Value, Gross Asset	$ 31.3	$ 115.3
Effect of counterparty netting	(30.4)	(100.6)
Variation margin (received) posted	0.0	(11.7)
Net derivatives and variation margin as classified in the balance sheets	0.9	3.0
Liability Derivative
Liability Derivative	(30.4)	(310.3)
Effect of counterparty netting	30.4	100.6
Variation margin (received) posted	0.0	209.7
Net derivatives and variation margin as classified in the balance sheets	0.0	0.0
Foreign currency option contracts
Asset Derivative
Derivative Asset, Fair Value, Gross Asset	0.9	3.0
Liability Derivative
Liability Derivative	0.0	0.0
Derivative contracts related to forecasted sales
Asset Derivative
Derivative Asset, Fair Value, Gross Asset	30.4	100.6
Liability Derivative
Liability Derivative	(15.4)	(310.3)
Financial trading contracts
Asset Derivative
Derivative Asset, Fair Value, Gross Asset	0.0	11.7
Liability Derivative
Liability Derivative	$ (15.0)	$ 0.0

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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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 10.0	$ (154.3)	$ 73.0	$ (510.9)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(19.3)	(122.9)	(55.5)	(192.6)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	29.3	(31.4)	128.5	(318.3)
Variation margin (received) posted	0.0		0.0		$ 209.7
Foreign currency option contracts
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(0.1)	(7.5)	(5.2)	(5.2)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(2.9)	(1.2)	(5.8)	(2.2)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	2.8	(6.3)	0.6	(3.0)
Derivative contracts related to forecasted sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	10.0	(147.1)	78.1	(516.1)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(30.3)	(122.6)	(80.9)	(190.6)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	40.3	(24.5)	159.0	(325.5)
Financial trading contracts
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.1	0.3	0.1	10.4
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	13.9	0.9	31.2	0.2
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	$ (13.8)	$ (0.6)	$ (31.1)	$ 10.2

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Derivatives and Fair Value Measurements - Financial Instruments Measured on Recurring Basis (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Derivative [Line Items]
Derivative assets (liabilities), at fair value	$ 1.2	$ (192.5)
Equity securities	0.3	2.5
Level 1
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Equity securities	0.0	0.0
Level 2
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.9	(195.0)
Equity securities	0.0	0.0
Level 3
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.3	2.5
Equity securities	0.3	2.5
Foreign currency option contracts
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.9	3.0
Foreign currency option contracts | Level 1
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Foreign currency option contracts | Level 2
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.9	3.0
Foreign currency option contracts | Level 3
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Derivative contracts related to forecasted sales
Derivative [Line Items]
Derivative assets (liabilities), at fair value	15.0	(209.7)
Derivative contracts related to forecasted sales | Level 1
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Derivative contracts related to forecasted sales | Level 2
Derivative [Line Items]
Derivative assets (liabilities), at fair value	15.0	(209.7)
Derivative contracts related to forecasted sales | Level 3
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Financial trading contracts
Derivative [Line Items]
Derivative assets (liabilities), at fair value	(15.0)	11.7
Financial trading contracts | Level 1
Derivative [Line Items]
Derivative assets (liabilities), at fair value	0.0	0.0
Financial trading contracts | Level 2
Derivative [Line Items]
Derivative assets (liabilities), at fair value	(15.0)	11.7
Financial trading contracts | Level 3
Derivative [Line Items]
Derivative assets (liabilities), at fair value	$ 0.0	$ 0.0

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Derivatives and Fair Value Measurements - Long-term debt (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Net carrying amount	$ 334.5	$ 333.8
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt at par value	343.5	343.6
Less: Unamortized debt issuance costs		(9.8)
Net carrying amount	334.5	333.8
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Estimated fair value	$ 454.8	$ 560.0

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Derivatives and Fair Value Measurements - Pre-Tax Gains and Losses on Hedging Derivatives (Details) - Designated as Hedging Instrument - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 10.0	$ (154.3)	$ 73.0	$ (510.9)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(19.3)	(122.9)	(55.5)	(192.6)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	29.3	(31.4)	128.5	(318.3)
Foreign currency option contracts
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(0.1)	(7.5)	(5.2)	(5.2)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(2.9)	(1.2)	(5.8)	(2.2)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	2.8	(6.3)	0.6	(3.0)
Derivative contracts related to forecasted sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	10.0	(147.1)	78.1	(516.1)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(30.3)	(122.6)	(80.9)	(190.6)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	40.3	(24.5)	159.0	(325.5)
Financial trading contracts
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.1	0.3	0.1	10.4
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	13.9	0.9	31.2	0.2
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	$ (13.8)	$ (0.6)	$ (31.1)	$ 10.2

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Property, Plant, Equipment and Mine Development (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Less: Accumulated depreciation, depletion and amortization	$ (1,933.2)	$ (1,787.0)
Property, plant, equipment and mine development, net	2,819.5	2,865.0
Land and coal interests
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	2,511.9	2,514.7
Buildings and improvements
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	628.8	594.2
Machinery and equipment
Property, Plant and Equipment [Line Items]
Property, Plant, Equipment, and mine development, gross	$ 1,612.0	$ 1,543.1

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Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Taxes
Income tax provision (benefit)	$ 74.2	$ 11.3	$ 192.2	$ 10.3
Foreign Tax Authority
Income Taxes
Remeasurement of income tax	$ 0.3	$ (3.5)	$ 0.7	$ (1.9)

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Long-term Debt - Schedule of Debt (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Debt Instrument [Line Items]
Finance lease obligations	$ 23.5		$ 23.5		$ 23.6
Less: Debt issuance costs	(9.0)		(9.0)		(9.8)
Total debt	334.5		334.5		333.8
Less: Current portion of long-term debt	13.0		13.0		13.2
Long-term debt	321.5		321.5		320.6
Interest expense	13.3	$ 37.6	31.7	$ 77.0
Interest Paid, Capitalized, Investing Activities	22.9	40.6	41.9	77.8
Other Noncash Income (Expense)	1.7	5.2
Noncash interest expense, net			3.3	9.0
Financial assurance instruments
Debt Instrument [Line Items]
Interest expense	8.0	13.6	20.0	27.1
Indebtedness
Debt Instrument [Line Items]
Interest expense	5.3	$ 24.0	11.7	$ 49.9
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%

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Long-term Debt - Narrative (Details) $ / shares in Units, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	May 31, 2023 $ / shares	Dec. 31, 2022 USD ($)	Mar. 01, 2022 USD ($)
Debt Instrument [Line Items]
Debt issuance cost	$ 9.0			$ 9.0			$ 9.8
Interest expense	13.3	$ 37.6		31.7	$ 77.0
Net loss on early debt extinguishment	2.0	2.3		8.8	25.8
Finance lease obligations	23.5			23.5			23.6
Interest Paid, Capitalized, Investing Activities	$ 22.9	$ 40.6		41.9	$ 77.8
Dividends Payable, Amount Per Share | $ / shares						$ 0.075
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				$ 29.2
8.500% Senior Secured Notes due December 20242 and 6.375% Senior Secured Notes due March 2025 [Domain]
Debt Instrument [Line Items]
Net loss on early debt extinguishment			$ 23.0
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	$ 320.0			$ 320.0			$ 320.0
Principal amount								$ 320.0
Debt Issuance Costs, Gross			11.2
Debt Conversion, Converted Instrument, Rate	1.00%
Debt Instrument, Convertible, Conversion Ratio	50.3816
Debt Instrument, Convertible, Conversion Ratio, Revised	50.5451
Senior Notes | 6.375% Senior Secured Notes due March 2025 (2025 Notes)
Debt Instrument [Line Items]
Debt repurchase, amount			257.4
Senior Notes | 8.500% Senior Secured Notes due December 2024 (2024 Peabody Notes)
Debt Instrument [Line Items]
Debt repurchase, amount			$ 62.6

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Pension and Postretirement Benefit Costs - Schedule of Net Periodic Benefit (Benefit) Cost (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Defined Benefit Plan Disclosure [Line Items]
Net periodic pension cost (credit)	$ (9.7)	$ (12.3)	$ (19.4)	$ (24.5)
Defined benefit pension plans
Defined Benefit Plan Disclosure [Line Items]
Interest cost on projected benefit obligation	7.4	5.4	14.8	10.7
Expected return on plan assets	(6.6)	(6.0)	(13.2)	(11.9)
Net periodic pension cost (credit)	0.8	(0.6)	1.6	(1.2)
Postretirement benefit plans
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	0.2	0.2	0.3	0.4
Interest cost on projected benefit obligation	2.5	1.8	5.0	3.5
Expected return on plan assets	(0.2)	(0.2)	(0.3)	(0.4)
Amortization of prior service credit	(13.4)	(13.5)	(26.8)	(26.9)
Net periodic pension cost (credit)	$ (10.9)	$ (11.7)	$ (21.8)	$ (23.4)

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Pension and Postretirement Benefit Costs - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Liability for Future Policy Benefits, Individual and Group Annuities and Supplementary Contracts	$ 500.0
Defined benefit pension plans
Defined Benefit Plan Disclosure [Line Items]
Funding threshold	80.00%
Defined Benefit Plan, Benefit Obligation, Payment for Settlement	$ 21.9

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Earnings per Share (EPS) - Narrative (Details) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Earnings Per Share [Abstract]
Antidilutive shares excluded from EPS calculation (in shares)	100,000	100,000	100,000	100,000

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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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Basic EPS numerator:
Weighted average shares outstanding — basic	142,300,000	144,000,000.0	143,400,000	140,100,000
Dilutive impact of share-based compensation awards	600,000	1,800,000	700,000	1,500,000
Dilutive impact of 2028 Convertible Notes	16,100,000	16,100,000	16,100,000	10,900,000
Basic income per share	$ 1.27	$ 2.85	$ 3.14	$ 2.08
Loss from discontinued operations	(0.01)	(0.01)	(0.02)	(0.01)
Basic income per share	$ 1.26	$ 2.84	$ 3.12	$ 2.07
Income from continuing operations, net of income taxes	$ 204.1	$ 411.3	$ 488.2	$ 291.5
Add: Tax adjusted interest expense related to 2028 Convertible Notes	3.5	2.5	6.1	3.5
Loss from discontinued operations, net of income taxes	(1.3)	(0.7)	(2.6)	(1.5)
Less: Net income attributable to noncontrolling interests	23.6	1.1	37.9	0.0
Income from continuing operations attributable to common stockholders	180.5	410.2	450.3	291.5
Income from continuing operations attributable to common stockholders	184.0	412.7	456.4	295.0
Net income attributable to common stockholders	$ 182.7	$ 412.0	$ 453.8	$ 293.5
Weighted average shares outstanding — diluted	159,000,000.0	161,900,000	160,200,000	152,500,000
Less: Net income attributable to noncontrolling interests	$ 23.6	$ 1.1	$ 37.9	$ 0.0
Income from continuing operations attributable to common stockholders	184.0	412.7	456.4	295.0
Loss from discontinued operations, net of income taxes	(1.3)	(0.7)	(2.6)	(1.5)
Net income attributable to common stockholders	$ 179.2	$ 409.5	$ 447.7	$ 290.0
Diluted EPS attributable to common stockholders:
Income from continuing operations	$ 1.16	$ 2.55	$ 2.85	$ 1.93
Loss from discontinued operations	(0.01)	(0.01)	(0.02)	0
Net income attributable to common stockholders	$ 1.15	$ 2.54	$ 2.83	$ 1.93
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Impact of dilutive securities (in shares)	16,100,000	16,100,000	16,100,000	10,900,000
Dilutive impact of 2028 Convertible Notes	16,100,000	16,100,000	16,100,000	10,900,000

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Financial Instruments and Other Guarantees (Details) - USD ($) $ in Millions	Jun. 30, 2023	Apr. 14, 2023	Mar. 31, 2023	Dec. 31, 2022
Guarantee Obligations [Line Items]
Restricted Cash	$ 731.4			$ 110.3
Deposits Assets	194.0			77.1
Restricted cash and collateral	925.4			187.4
LC Facility
Guarantee Obligations [Line Items]
Deposits Assets	0.0			28.5
Surety Trust Account
Guarantee Obligations [Line Items]
Restricted Cash	558.2		$ 566.3	0.0
Collateralized letters of credit funding
Guarantee Obligations [Line Items]
Restricted Cash	173.2			110.3
Deposits with Regulatory Authorities
Guarantee Obligations [Line Items]
Deposits Assets	194.0			33.6
Deposits Held on Behalf of Surety
Guarantee Obligations [Line Items]
Deposits Assets	0.0			15.0
Asset Retirement Obligations
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	23.8			437.8
Surety Bonds and Letters of Credit Outstanding for Reclamation Support	1,142.8			1,687.9
Letters of Credit in Support of Surety Bonds	(23.8)			(431.7)
Total Obligations Supported, Net	1,119.0			1,256.2
Surety bonds amount	1,119.0			1,250.1
Asset Retirement and Other Obligations
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	117.8			569.6
Total Surety Bonds and Letters of Credit Outstanding	1,349.9			1,946.4
Total Letters of Credit in Support of Surety Bonds	(29.7)			(468.9)
Total Obligations Supported, Net	1,320.2			1,477.5
Surety bonds amount	1,232.1			1,376.8
Other Obligations
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	94.0			131.8
Surety Bonds and Letters of Credit Outstanding for Other Support	207.1			258.5
Letters of Credit in Support of Surety Bonds	(5.9)			(37.2)
Total Obligations Supported, Net	201.2			221.3
Surety bonds amount	$ 113.1			$ 126.7
LC Facility
Guarantee Obligations [Line Items]
Mandatory Repurchase, Percentage of Accreted Value	95.00%
Debt instrument, repurchase amount	$ 30.0	$ 30.0
Secured debt | Accounts Receivable Securitization Program
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	117.8
Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	$ 168.2

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Financial Instruments and Other Guarantees - Narratives (Details) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Apr. 14, 2023 USD ($)	Mar. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Nov. 06, 2020 USD ($)
Guarantee Obligations [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 237.2			$ 237.2
Cumulative Collateral	557.8
Net loss on early debt extinguishment	2.0	$ 2.3		8.8	$ 25.8
Interest expense	13.3	37.6		31.7	77.0
Restricted Cash	731.4			731.4				$ 110.3
Difference between penal sum of all surety bonds and amount of collateral posted in favor of surety providers	533.6			$ 533.6
Letter of Credit
Guarantee Obligations [Line Items]
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%
Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	168.2			$ 168.2
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	$ 173.2			$ 173.2
Stated interest rate	0.75%			0.75%
Surety Trust Account
Guarantee Obligations [Line Items]
Restricted Cash	$ 558.2			$ 558.2			$ 566.3	$ 0.0
Accounts Receivable Securitization Program
Guarantee Obligations [Line Items]
Line of Credit Facility, Previous Maximum Borrowing Capacity	175.0			175.0
Line of credit facility, maximum borrowing capacity	225.0			225.0
Accounts Receivable Securitization Program | Secured debt
Guarantee Obligations [Line Items]
Letters of credit outstanding, amount	117.8			$ 117.8
Basis spread on variable rate				2.10%
Maximum
Guarantee Obligations [Line Items]
Debt Instrument, Collateral Amount						$ 721.8
Maximum | Collateralized Letter of Credit Agreement
Guarantee Obligations [Line Items]
Transaction support agreements, additional collateral demands	5.0			$ 5.0
Surety Bond
Guarantee Obligations [Line Items]
Debt Instrument, Transaction Support Agreements, Additional Collateral Posted	140.5			140.5
Debt Instrument, Transaction Support Agreement, Additional Collateral Held	$ 15.0			$ 15.0
Surety Agreement Liquidity Covenant, Amount						$ 400.0
Debt instrument, transaction support agreements, fair value of second liens on mining equipment									$ 200.0
Surety Bond | Maximum
Guarantee Obligations [Line Items]
Net Leverage Ratio						1.5
Surety Bond | Minimum
Guarantee Obligations [Line Items]
Net Leverage Ratio						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%
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	34.8			34.8
Interest expense	$ 0.8	$ 0.9		$ 1.9	$ 1.8

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Commitments and Contingencies (Details) $ in Millions	Jun. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	Oct. 09, 2015 buyer	Dec. 31, 2007 USD ($)
Patriot
Long-term Purchase Commitment [Line Items]
Number of buyers | buyer			2
Black Lung Occupational Disease Liability | Patriot | Spinoff
Long-term Purchase Commitment [Line Items]
Initially determined potential exposure from patriot bankruptcy				$ 150.0
Black Lung Occupational Disease Liability | Patriot | Disposal Group, Disposed of by Means Other than Sale, Not Discontinued Operations
Long-term Purchase Commitment [Line Items]
Initially determined potential exposure from patriot bankruptcy	$ 80.0	$ 82.3
Capital Addition Purchase Commitments
Long-term Purchase Commitment [Line Items]
Unrecorded unconditional purchase obligation (within next five years)	100.8
Unrecorded unconditional purchase obligation (within next 12 months)	$ 94.1

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Segment Information - Segment Results (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Reportable segment results
Revenues	$ 1,268.8	$ 1,321.9	$ 2,632.8	$ 2,013.3
Adjusted EBITDA	358.2	577.8	748.8	905.3
Seaborne Thermal
Reportable segment results
Revenues	399.5	354.9	746.0	606.1
Adjusted EBITDA	197.5	176.8	361.5	267.3
Seaborne Metallurgical
Reportable segment results
Revenues	372.5	533.8	660.9	855.1
Adjusted EBITDA	102.5	299.7	193.3	480.7
Powder River Basin
Reportable segment results
Revenues	259.7	229.7	565.0	480.9
Adjusted EBITDA	26.2	(2.0)	62.0	5.6
Other U.S. Thermal
Reportable segment results
Revenues	199.9	224.9	449.3	428.0
Adjusted EBITDA	51.9	61.9	116.1	111.9
Corporate and Other (1)
Reportable segment results
Revenues	37.2	(21.4)	211.6	(356.8)
Adjusted EBITDA	$ (19.9)	$ 41.4	$ 15.9	$ 39.8

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Segment Information - Reconciliation to Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Segment Reporting Information [Line Items]
Income from continuing operations, net of income taxes	$ 204.1	$ 411.3	$ 488.2	$ 291.5
Depreciation, depletion and amortization	80.6	73.8	156.9	146.7
Asset retirement obligation expenses	15.5	12.7	30.9	27.7
Restructuring charges	2.0	0.2	2.1	1.8
Asset impairment	0.0	0.0	2.0	0.0
Provision for NARM and Shoal Creek loss	33.7	0.0	33.7	0.0
Changes in amortization of basis difference related to equity affiliates	(0.4)	(0.6)	(0.7)	(1.2)
Interest expense	13.3	37.6	31.7	77.0
Net loss on early debt extinguishment	2.0	2.3	8.8	25.8
Interest income	(23.1)	(0.9)	(36.2)	(1.4)
Unrealized (gains) losses on derivative contracts related to forecasted sales	(40.3)	24.5	(159.0)	325.5
Unrealized (gains) losses on foreign currency option contracts	(2.8)	6.3	(0.6)	3.0
Take-or-pay contract-based intangible recognition	(0.6)	(0.7)	(1.2)	(1.4)
Income tax provision	74.2	11.3	192.2	10.3
Adjusted EBITDA	$ 358.2	$ 577.8	$ 748.8	$ 905.3

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Other Events Narrative (Details) $ in Millions, $ in Millions		1 Months Ended	3 Months Ended			6 Months Ended
	Jul. 05, 2023 USD ($)	Jul. 28, 2023 USD ($) shares	Jun. 30, 2023 USD ($) shares	Jun. 30, 2023 AUD ($) shares	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)
Other Commercial Events [Line Items]
Revenues			$ 1,268.8		$ 1,321.9	$ 2,632.8	$ 2,013.3
Other Noncash Income			9.3		0.0	9.2
Revenue from Collaborative Arrangement, Excluding Revenue from Contract with Customer				$ 30.0
Revenue related to excess port and rail capacity agreement			19.2
Provision for Other Losses			28.7			28.7
Storm Damage Provision			5.0			5.0
Storm damage provision for materials and supplies inventories			4.0			4.0
Storm damage provision for buildings and equipment			$ 1.0			1.0
Common stock, shares, acquired | shares			8,900,000	8,900,000
Common stock repurchase amount including commission fees			$ 184.2
Provision for other losses related to longwall development and other costs			17.8			17.8
Provision for other losses for equipment			10.9			10.9
Subsequent Event
Other Commercial Events [Line Items]
Common stock, shares, acquired | shares		3,100,000
Common stock repurchase amount including commission fees	$ 11.2	$ 67.0
Treasury Stock, Common
Other Commercial Events [Line Items]
Sales and Excise Tax Payable			$ 1.6		$ 0.0	$ 1.6	$ 0.0