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

September 30, ~~2021~~2022

☐

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 ☑

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ☑ No ☐

There were ~~127.4~~143.9 million shares of the registrant’s common stock (par value of $0.01 per share) outstanding at ~~November 2, 2021.~~October 31, 2022.

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			3229
Item 3. Quantitative and Qualitative Disclosures About Market Risk			5654
Item 4. Controls and Procedures			5655
PART II — OTHER INFORMATION
Item 1. Legal Proceedings			5655
Item 1A. Risk Factors			5655
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			5857
Item 4. Mine Safety Disclosures			5958

Item 6. Exhibits			6058
EXHIBIT INDEX			6159
SIGNATURE			6260

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions, except per share data)
Revenues $ 679.0 $ 671.0 $ 2,053.7 $ 2,143.9
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below) 649.4 550.9 1,843.4 1,886.7
Depreciation, depletion and amortization 77.9 72.2 223.3 266.5
Asset retirement obligation expenses 14.3 14.3 45.3 46.0
Selling and administrative expenses 21.1 27.2 64.2 77.3
Restructuring charges 1.7 8.1 5.9 31.1
Transaction costs related to joint ventures — 6.0 — 23.1
Other operating (income) loss:
Net gain on disposals (25.8) (2.5) (28.2) (10.4)
Asset impairment — — — 1,418.1
(Income) loss from equity affiliates (15.8) 10.6 (11.4) 25.7
Operating loss (43.8) (15.8) (88.8) (1,620.2)
Interest expense 45.5 34.9 143.3 102.3
Net gain on early debt extinguishment (16.0) — (31.3) —
Interest income (1.4) (1.6) (4.2) (7.1)
Net periodic benefit (credit) costs, excluding service cost (8.6) 2.8 (26.0) 8.3
Net mark-to-market adjustment on actuarially determined liabilities — 13.0 — 13.0
Loss from continuing operations before income taxes (63.3) (64.9) (170.6) (1,736.7)
Income tax (benefit) provision (3.7) (0.1) (10.3) 2.7
Loss from continuing operations, net of income taxes (59.6) (64.8) (160.3) (1,739.4)
Income (loss) from discontinued operations, net of income taxes 24.3 (2.3) 20.0 (6.8)
Net loss (35.3) (67.1) (140.3) (1,746.2)
Less: Net income (loss) attributable to noncontrolling interests 8.9 0.1 12.6 (5.1)
Net loss attributable to common stockholders $ (44.2) $ (67.2) $ (152.9) $ (1,741.1)
Loss from continuing operations:
Basic loss per share $ (0.60) $ (0.66) $ (1.65) $ (17.76)
Diluted loss per share $ (0.60) $ (0.66) $ (1.65) $ (17.76)
Net loss attributable to common stockholders:
Basic loss per share $ (0.38) $ (0.69) $ (1.46) $ (17.83)
Diluted loss per share $ (0.38) $ (0.69) $ (1.46) $ (17.83)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions, except per share data)
Revenue	$	1,342.5	$	679.0	$	3,355.8	$	2,053.7
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	838.4		649.4		2,363.0		1,843.4
Depreciation, depletion and amortization	80.7		77.9		227.4		223.3
Asset retirement obligation expenses	13.1		14.3		40.8		45.3
Selling and administrative expenses	19.6		21.1		64.5		64.2
Restructuring charges	1.0		1.7		2.8		5.9

Other operating (income) loss:
Net gain on disposals	(5.0)		(25.8)		(22.7)		(28.2)
Asset impairment	1.7		—		1.7		—


Income from equity affiliates	(27.5)		(15.8)		(120.9)		(11.4)
Operating profit (loss)	420.5		(43.8)		799.2		(88.8)
Interest expense	33.8		45.5		110.8		143.3
Net loss (gain) on early debt extinguishment	8.7		(16.0)		34.5		(31.3)
Interest income	(4.9)		(1.4)		(6.3)		(4.2)
Net periodic benefit credit, excluding service cost	(12.2)		(8.6)		(36.7)		(26.0)


Income (loss) from continuing operations before income taxes	395.1		(63.3)		696.9		(170.6)
Income tax provision (benefit)	10.7		(3.7)		21.0		(10.3)
Income (loss) from continuing operations, net of income taxes	384.4		(59.6)		675.9		(160.3)
(Loss) income from discontinued operations, net of income taxes	(0.8)		24.3		(2.3)		20.0
Net income (loss)	383.6		(35.3)		673.6		(140.3)

Less: Net income attributable to noncontrolling interests	8.5		8.9		8.5		12.6
Net income (loss) attributable to common stockholders	$	375.1	$	(44.2)	$	665.1	$	(152.9)

Income (loss) from continuing operations:
Basic income (loss) per share	$	2.61	$	(0.60)	$	4.72	$	(1.65)
Diluted income (loss) per share	$	2.34	$	(0.60)	$	4.33	$	(1.65)
Net income (loss) attributable to common stockholders:
Basic income (loss) per share	$	2.60	$	(0.38)	$	4.70	$	(1.46)
Diluted income (loss) per share	$	2.33	$	(0.38)	$	4.31	$	(1.46)

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Net loss $ (35.3) $ (67.1) $ (140.3) $ (1,746.2)
Postretirement plans (net of $0.0 tax provisions in each period) (11.0) 172.3 (33.0) 167.9
Foreign currency translation adjustment (0.8) 2.5 (1.2) 1.8
Other comprehensive (loss) income, net of income taxes (11.8) 174.8 (34.2) 169.7
Comprehensive (loss) income (47.1) 107.7 (174.5) (1,576.5)
Less: Net income (loss) attributable to noncontrolling interests 8.9 0.1 12.6 (5.1)
Comprehensive (loss) income attributable to common stockholders $ (56.0) $ 107.6 $ (187.1) $ (1,571.4)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Net income (loss)	$	383.6	$	(35.3)	$	673.6	$	(140.3)










Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)		(11.0)		(40.3)		(33.0)




Foreign currency translation adjustment	0.1		(0.8)		(1.4)		(1.2)
Other comprehensive loss, net of income taxes	(13.3)		(11.8)		(41.7)		(34.2)
Comprehensive income (loss)	370.3		(47.1)		631.9		(174.5)

Less: Net income attributable to noncontrolling interests	8.5		8.9		8.5		12.6
Comprehensive income (loss) attributable to common stockholders	$	361.8	$	(56.0)	$	623.4	$	(187.1)

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents

PEABODY ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS


		(Unaudited)					(Unaudited)
		September 30, 2021		December 31, 2020			September 30, 2022		December 31, 2021
		(Amounts in millions, except per share data)					(Amounts in millions, except per share data)
ASSETS	ASSETS					ASSETS
Current assets	Current assets					Current assets
Cash and cash equivalents	Cash and cash equivalents	$	587.0	$	709.2	Cash and cash equivalents	$	1,354.5	$	954.3

Accounts receivable, net of allowance for credit losses of $0.0 at September 30, 2021 and December 31, 2020		276.0		244.8
Inventories		224.5		261.6
Accounts receivable, net of allowance for credit losses of $0.0 at September 30, 2022 and December 31, 2021						Accounts receivable, net of allowance for credit losses of $0.0 at September 30, 2022 and December 31, 2021	426.4		350.5
Inventories, net						Inventories, net	277.4		226.7

Other current assets	Other current assets	223.8		204.7		Other current assets	305.8		270.2
Total current assets	Total current assets	1,311.3		1,420.3		Total current assets	2,364.1		1,801.7
Property, plant, equipment and mine development, net	Property, plant, equipment and mine development, net	2,952.0		3,051.1		Property, plant, equipment and mine development, net	2,817.6		2,950.6

Operating lease right-of-use assets	Operating lease right-of-use assets	38.4		49.9		Operating lease right-of-use assets	29.0		35.5
Investments and other assets	Investments and other assets	140.8		140.9		Investments and other assets	220.3		162.0
Deferred income taxes		—		4.9

Total assets	Total assets	$	4,442.5	$	4,667.1	Total assets	$	5,431.0	$	4,949.8

LIABILITIES AND STOCKHOLDERS’ EQUITY	LIABILITIES AND STOCKHOLDERS’ EQUITY					LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities	Current liabilities					Current liabilities
Current portion of long-term debt	Current portion of long-term debt	$	59.5	$	44.9	Current portion of long-term debt	$	546.9	$	59.6

Accounts payable and accrued expenses	Accounts payable and accrued expenses	761.7		745.7		Accounts payable and accrued expenses	771.2		872.1
Total current liabilities	Total current liabilities	821.2		790.6		Total current liabilities	1,318.1		931.7
Long-term debt, less current portion	Long-term debt, less current portion	1,268.7		1,502.9		Long-term debt, less current portion	322.3		1,078.2
Deferred income taxes	Deferred income taxes	13.0		35.0		Deferred income taxes	24.5		27.3
Asset retirement obligations	Asset retirement obligations	641.9		650.5		Asset retirement obligations	660.8		654.8
Accrued postretirement benefit costs	Accrued postretirement benefit costs	402.2		413.2		Accrued postretirement benefit costs	203.9		212.1
Operating lease liabilities, less current portion	Operating lease liabilities, less current portion	31.6		42.1		Operating lease liabilities, less current portion	13.3		27.2
Other noncurrent liabilities	Other noncurrent liabilities	221.6		251.5		Other noncurrent liabilities	226.9		197.7
Total liabilities	Total liabilities	3,400.2		3,685.8		Total liabilities	2,769.8		3,129.0
Stockholders’ equity	Stockholders’ equity					Stockholders’ equity

Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of September 30, 2021 and December 31, 2020		—		—
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of September 30, 2021 and December 31, 2020		—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 165.3 shares issued and 122.3 shares outstanding as of September 30, 2021 and 140.5 shares issued and 97.8 shares outstanding as of December 31, 2020		1.6		1.4
Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of September 30, 2022 and December 31, 2021						Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of September 30, 2022 and December 31, 2021	—		—
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of September 30, 2022 and December 31, 2021						Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of September 30, 2022 and December 31, 2021	—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 187.1 shares issued and 143.9 shares outstanding as of September 30, 2022 and 176.3 shares issued and 133.3 shares outstanding as of December 31, 2021						Common Stock — $0.01 per share par value; 450.0 shares authorized, 187.1 shares issued and 143.9 shares outstanding as of September 30, 2022 and 176.3 shares issued and 133.3 shares outstanding as of December 31, 2021	1.9		1.8
Additional paid-in capital	Additional paid-in capital	3,605.1		3,364.6		Additional paid-in capital	3,974.1		3,745.6
Treasury stock, at cost — 43.0 and 42.7 common shares as of September 30, 2021 and December 31, 2020		(1,370.2)		(1,368.9)
Treasury stock, at cost — 43.2 and 43.0 common shares as of September 30, 2022 and December 31, 2021						Treasury stock, at cost — 43.2 and 43.0 common shares as of September 30, 2022 and December 31, 2021	(1,372.9)		(1,370.3)
Accumulated deficit	Accumulated deficit	(1,426.2)		(1,273.3)		Accumulated deficit	(248.1)		(913.2)
Accumulated other comprehensive income	Accumulated other comprehensive income	171.6		205.8		Accumulated other comprehensive income	256.2		297.9
Peabody Energy Corporation stockholders’ equity	Peabody Energy Corporation stockholders’ equity	981.9		929.6		Peabody Energy Corporation stockholders’ equity	2,611.2		1,761.8
Noncontrolling interests	Noncontrolling interests	60.4		51.7		Noncontrolling interests	50.0		59.0
Total stockholders’ equity	Total stockholders’ equity	1,042.3		981.3		Total stockholders’ equity	2,661.2		1,820.8
Total liabilities and stockholders’ equity	Total liabilities and stockholders’ equity	$	4,442.5	$	4,667.1	Total liabilities and stockholders’ equity	$	5,431.0	$	4,949.8

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents


PEABODY ENERGY CORPORATION	PEABODY ENERGY CORPORATION					PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS	UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS					UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

		Nine Months Ended September 30,					Nine Months Ended September 30,
		2021		2020			2022		2021
		(Dollars in millions)					(Dollars in millions)
Cash Flows From Operating Activities	Cash Flows From Operating Activities					Cash Flows From Operating Activities
Net loss		$	(140.3)	$	(1,746.2)
(Income) loss from discontinued operations, net of income taxes		(20.0)		6.8
Loss from continuing operations, net of income taxes		(160.3)		(1,739.4)
Adjustments to reconcile loss from continuing operations, net of income taxes to net cash used in operating activities:
Net income (loss)						Net income (loss)	$	673.6	$	(140.3)
Loss (income) from discontinued operations, net of income taxes						Loss (income) from discontinued operations, net of income taxes	2.3		(20.0)
Income (loss) from continuing operations, net of income taxes						Income (loss) from continuing operations, net of income taxes	675.9		(160.3)
Adjustments to reconcile income (loss) from continuing operations, net of income taxes to net cash provided by (used in) operating activities:						Adjustments to reconcile income (loss) from continuing operations, net of income taxes to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	Depreciation, depletion and amortization	223.3		266.5		Depreciation, depletion and amortization	227.4		223.3
Noncash interest expense, net	Noncash interest expense, net	15.2		12.0		Noncash interest expense, net	13.6		15.2

Deferred income taxes	Deferred income taxes	(22.0)		0.1		Deferred income taxes	(2.8)		(22.0)
Noncash share-based compensation	Noncash share-based compensation	5.6		9.9		Noncash share-based compensation	6.6		5.6
Asset impairment	Asset impairment	—		1,418.1		Asset impairment	1.7		—
Net gain on disposals	Net gain on disposals	(28.2)		(10.4)		Net gain on disposals	(22.7)		(28.2)
Net gain on early debt extinguishment		(31.3)		—
(Income) loss from equity affiliates		(11.4)		25.7
Net loss (gain) on early debt extinguishment						Net loss (gain) on early debt extinguishment	34.5		(31.3)
Income from equity affiliates						Income from equity affiliates	(120.9)		(11.4)

Foreign currency option contracts	Foreign currency option contracts	5.3		(5.2)		Foreign currency option contracts	4.4		5.3
Changes in current assets and liabilities:	Changes in current assets and liabilities:					Changes in current assets and liabilities:
Accounts receivable	Accounts receivable	(31.1)		136.6		Accounts receivable	(75.9)		(31.1)
Inventories	Inventories	37.1		11.9		Inventories	(50.7)		37.1
Other current assets	Other current assets	(11.1)		0.3		Other current assets	(40.6)		(11.1)
Accounts payable and accrued expenses	Accounts payable and accrued expenses	42.5		(136.3)		Accounts payable and accrued expenses	(61.6)		42.5
Collateral arrangements	Collateral arrangements	(5.0)		—		Collateral arrangements	(36.8)		(5.0)
Asset retirement obligations	Asset retirement obligations	17.4		12.2		Asset retirement obligations	6.0		17.4
Workers’ compensation obligations	Workers’ compensation obligations	—		(1.3)		Workers’ compensation obligations	(2.5)		—
Postretirement benefit obligations	Postretirement benefit obligations	(43.9)		(6.1)		Postretirement benefit obligations	(48.5)		(43.9)
Pension obligations	Pension obligations	(1.8)		0.3		Pension obligations	(1.7)		(1.8)
Other, net	Other, net	0.2		(4.6)		Other, net	3.5		0.2
Net cash provided by (used in) continuing operations		0.5		(9.7)
Net cash provided by continuing operations						Net cash provided by continuing operations	508.9		0.5
Net cash used in discontinued operations	Net cash used in discontinued operations	(18.9)		(22.4)		Net cash used in discontinued operations	(4.8)		(18.9)
Net cash used in operating activities		(18.4)		(32.1)
Net cash provided by (used in) operating activities						Net cash provided by (used in) operating activities	504.1		(18.4)

Table of Contents


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

		Nine Months Ended September 30,					Nine Months Ended September 30,
		2021		2020			2022		2021
		(Dollars in millions)					(Dollars in millions)
Cash Flows From Investing Activities	Cash Flows From Investing Activities					Cash Flows From Investing Activities
Additions to property, plant, equipment and mine development	Additions to property, plant, equipment and mine development	(123.6)		(131.9)		Additions to property, plant, equipment and mine development	(104.5)		(123.6)
Changes in accrued expenses related to capital expenditures	Changes in accrued expenses related to capital expenditures	(3.3)		(14.9)		Changes in accrued expenses related to capital expenditures	(8.3)		(3.3)

Proceeds from disposal of assets, net of receivables	Proceeds from disposal of assets, net of receivables	12.7		15.4		Proceeds from disposal of assets, net of receivables	30.6		12.7

Contributions to joint ventures	Contributions to joint ventures	(363.8)		(275.2)		Contributions to joint ventures	(475.1)		(363.8)
Distributions from joint ventures	Distributions from joint ventures	350.3		271.0		Distributions from joint ventures	465.2		350.3
Advances to related parties	Advances to related parties	(0.4)		(23.1)		Advances to related parties	(1.3)		(0.4)
Cash receipts from Middlemount Coal Pty Ltd and other related parties	Cash receipts from Middlemount Coal Pty Ltd and other related parties	8.4		—		Cash receipts from Middlemount Coal Pty Ltd and other related parties	154.9		8.4

Other, net	Other, net	—		(0.7)		Other, net	(0.4)		—
Net cash used in investing activities		(119.7)		(159.4)
Net cash provided by (used in) investing activities						Net cash provided by (used in) investing activities	61.1		(119.7)
Cash Flows From Financing Activities	Cash Flows From Financing Activities					Cash Flows From Financing Activities
Proceeds from long-term debt	Proceeds from long-term debt	—		360.0		Proceeds from long-term debt	545.0		—
Repayments of long-term debt	Repayments of long-term debt	(133.6)		(81.0)		Repayments of long-term debt	(846.3)		(133.6)
Payment of debt issuance and other deferred financing costs	Payment of debt issuance and other deferred financing costs	(22.5)		—		Payment of debt issuance and other deferred financing costs	(21.1)		(22.5)
Proceeds from common stock issuances, net of costs	Proceeds from common stock issuances, net of costs	177.2		—		Proceeds from common stock issuances, net of costs	222.0		177.2
Repurchase of employee common stock relinquished for tax withholding	Repurchase of employee common stock relinquished for tax withholding	(1.3)		(1.6)		Repurchase of employee common stock relinquished for tax withholding	(2.6)		(1.3)

Distributions to noncontrolling interests	Distributions to noncontrolling interests	(3.9)		(3.5)		Distributions to noncontrolling interests	(17.5)		(3.9)

Net cash provided by financing activities		15.9		273.9
Net cash (used in) provided by financing activities						Net cash (used in) provided by financing activities	(120.5)		15.9
Net change in cash, cash equivalents and restricted cash	Net change in cash, cash equivalents and restricted cash	(122.2)		82.4		Net change in cash, cash equivalents and restricted cash	444.7		(122.2)
Cash, cash equivalents and restricted cash at beginning of period	Cash, cash equivalents and restricted cash at beginning of period	709.2		732.2		Cash, cash equivalents and restricted cash at beginning of period	954.3		709.2
Cash, cash equivalents and restricted cash at end of period(1)	Cash, cash equivalents and restricted cash at end of period(1)	$	587.0	$	814.6	Cash, cash equivalents and restricted cash at end of period(1)	$	1,399.0	$	587.0

(1) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at end of period” at September 30, 2022						(1) The following table provides a reconciliation of “Cash, cash equivalents and restricted cash at end of period” at September 30, 2022
Cash and cash equivalents						Cash and cash equivalents	$	1,354.5
Restricted cash included in “Investments and other assets”						Restricted cash included in “Investments and other assets”	44.5
Cash, cash equivalents and restricted cash at end of period						Cash, cash equivalents and restricted cash at end of period	$	1,399.0

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(Dollars in millions)									(Dollars in millions)

Common Stock	Common Stock									Common Stock
Balance, beginning of period	Balance, beginning of period	$	1.5	$	1.4	$	1.4	$	1.4	Balance, beginning of period	$	1.9	$	1.5	$	1.8	$	1.4

Common stock issuances, net of costs	Common stock issuances, net of costs	0.1		—		0.2		—		Common stock issuances, net of costs	—		0.1		0.1		0.2
Balance, end of period	Balance, end of period	1.6		1.4		1.6		1.4		Balance, end of period	1.9		1.6		1.9		1.6
Additional paid-in capital	Additional paid-in capital									Additional paid-in capital
Balance, beginning of period	Balance, beginning of period	3,463.8		3,357.2		3,364.6		3,351.1		Balance, beginning of period	3,972.9		3,463.8		3,745.6		3,364.6

Share-based compensation for equity-classified awards	Share-based compensation for equity-classified awards	1.7		3.8		5.6		9.9		Share-based compensation for equity-classified awards	1.2		1.7		6.6		5.6

Common stock issued in exchange for debt retirement	Common stock issued in exchange for debt retirement	27.7		—		58.2		—		Common stock issued in exchange for debt retirement	—		27.7		—		58.2
Common stock issuances, net of costs	Common stock issuances, net of costs	111.9		—		176.7		—		Common stock issuances, net of costs	—		111.9		221.9		176.7

Balance, end of period	Balance, end of period	3,605.1		3,361.0		3,605.1		3,361.0		Balance, end of period	3,974.1		3,605.1		3,974.1		3,605.1
Treasury stock	Treasury stock									Treasury stock
Balance, beginning of period	Balance, beginning of period	(1,370.2)		(1,368.9)		(1,368.9)		(1,367.3)		Balance, beginning of period	(1,372.9)		(1,370.2)		(1,370.3)		(1,368.9)

Repurchase of employee common stock relinquished for tax withholding	Repurchase of employee common stock relinquished for tax withholding	—		—		(1.3)		(1.6)		Repurchase of employee common stock relinquished for tax withholding	—		—		(2.6)		(1.3)
Balance, end of period	Balance, end of period	(1,370.2)		(1,368.9)		(1,370.2)		(1,368.9)		Balance, end of period	(1,372.9)		(1,370.2)		(1,372.9)		(1,370.2)
(Accumulated deficit) retained earnings
Accumulated deficit										Accumulated deficit
Balance, beginning of period	Balance, beginning of period	(1,382.0)		(1,076.9)		(1,273.3)		597.0		Balance, beginning of period	(623.2)		(1,382.0)		(913.2)		(1,273.3)
Net loss attributable to common stockholders		(44.2)		(67.2)		(152.9)		(1,741.1)
Net income (loss) attributable to common stockholders										Net income (loss) attributable to common stockholders	375.1		(44.2)		665.1		(152.9)

Balance, end of period	Balance, end of period	(1,426.2)		(1,144.1)		(1,426.2)		(1,144.1)		Balance, end of period	(248.1)		(1,426.2)		(248.1)		(1,426.2)
Accumulated other comprehensive income	Accumulated other comprehensive income									Accumulated other comprehensive income
Balance, beginning of period	Balance, beginning of period	183.4		26.5		205.8		31.6		Balance, beginning of period	269.5		183.4		297.9		205.8

Postretirement plans (net of $0.0 tax provisions in each period)	Postretirement plans (net of $0.0 tax provisions in each period)	(11.0)		172.3		(33.0)		167.9		Postretirement plans (net of $0.0 tax provisions in each period)	(13.4)		(11.0)		(40.3)		(33.0)
Foreign currency translation adjustment	Foreign currency translation adjustment	(0.8)		2.5		(1.2)		1.8		Foreign currency translation adjustment	0.1		(0.8)		(1.4)		(1.2)
Balance, end of period	Balance, end of period	171.6		201.3		171.6		201.3		Balance, end of period	256.2		171.6		256.2		171.6
Noncontrolling interests	Noncontrolling interests									Noncontrolling interests
Balance, beginning of period	Balance, beginning of period	55.3		50.0		51.7		58.7		Balance, beginning of period	45.2		55.3		59.0		51.7
Net income (loss) attributable to noncontrolling interests		8.9		0.1		12.6		(5.1)
Net income attributable to noncontrolling interests										Net income attributable to noncontrolling interests	8.5		8.9		8.5		12.6
Distributions to noncontrolling interests	Distributions to noncontrolling interests	(3.8)		—		(3.9)		(3.5)		Distributions to noncontrolling interests	(3.7)		(3.8)		(17.5)		(3.9)
Balance, end of period	Balance, end of period	60.4		50.1		60.4		50.1		Balance, end of period	50.0		60.4		50.0		60.4
Total stockholders’ equity	Total stockholders’ equity	$	1,042.3	$	1,100.8	$	1,042.3	$	1,100.8	Total stockholders’ equity	$	2,661.2	$	1,042.3	$	2,661.2	$	1,042.3

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents

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, ~~revenues~~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, ~~2020.~~2021. 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, ~~2020~~2021 has been derived from the Company’s audited consolidated balance sheet at that date. The Company’s results of operations for the three and nine months ended September 30, ~~2021~~2022 are not necessarily indicative of the results that may be expected for future quarters or for the year ending December 31, ~~2021.~~2022.

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

Newly Adopted Accounting Standards

~~Equity Method Investments.~~Convertible Debt. In ~~January~~August 2020, the Financial Accounting Standards Board ~~(FASB)~~ issued Accounting Standards Update (ASU) ~~2020-01,~~2020-06, which ~~clarifies~~simplifies the ~~interactions between~~accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. Among other changes, ASU 2020-06 removes from U.S. GAAP the liability and equity separation model for convertible instruments with a cash conversion feature, and as a result, after adoption, entities will no longer separately present in equity an embedded conversion feature for such debt. Similarly, the embedded conversion feature will no longer be amortized into income as interest expense over the life of the instrument. Instead, entities will account for a convertible debt instrument wholly as debt unless (1) a convertible instrument contains features that require bifurcation as a derivative under Accounting Standards Codification ~~(ASC) 321, ASC 323~~Topic 815, Derivatives and ~~ASC 815.~~Hedging or (2) a convertible debt instrument was issued at a substantial premium. Additionally, ASU 2020-06 requires the application of the if-converted method to calculate the impact of convertible instruments on diluted earnings per share. ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, and can be adopted on either a fully retrospective or modified retrospective basis. The Company adopted ASU 2020-06, effective January 1, 2022. In the Company’s accompanying condensed consolidated balance sheets, the adoption of the new ~~guidance addresses~~standard impacted the accounting for the ~~transition into and out~~Company’s $320.0 million of convertible debt issued in March 2022, as further described in Note 9. “Long-term Debt.” In particular, because the related senior notes have cash conversion features, bifurcation of the principal balance between debt and equity is no longer applicable. Additionally, this guidance requires the application of the “if-converted” method ~~and measuring certain purchased options and forward contracts~~ to ~~acquire investments. ASU 2020-01 is effective~~calculate the impact of convertible instruments on ~~January 1, 2021 for calendar year-end public companies. The Company adopted the requirements effective January 1, 2021. The adoption of this ASU did not have a material impact on~~diluted earnings per share, as reflected in the Company’s ~~consolidated financial statements or disclosures.~~calculations within Note 11. “Earnings per Share (EPS).”

Accounting Standards Not Yet Implemented

Reference Rate Reform. In March 2020, ASU 2020-04 was issued, which provides temporary optional ~~guidance for a limited period of time~~expedients to ~~ease~~applying the ~~potential burden on accounting for contract modifications caused by~~ reference rate reform ~~(including reform of the~~guidance to contracts that reference London Interbank Offered Rate (LIBOR) or ~~other~~another reference rate ~~reform).~~expected to be discontinued. Under this update, contract modifications resulting in a new reference rate may be accounted for as a continuation of the existing contract. This guidance is effective ~~for all entities as~~upon issuance of ~~March 12, 2020~~the update and applies to contract modifications made through December 31, 2022. The ~~guidance may~~Company has certain debt which utilizes a U.S. Dollar one-month LIBOR rate, which is expected to be ~~adopted over time as reference~~published until June 2023. The LIBOR rate ~~reform activities occur and should~~is likely to be ~~applied on~~replaced by a ~~prospective basis.~~similar secured or unsecured overnight financing rate. The Company ~~is still completing its evaluation of~~cannot estimate the impact of ~~the guidance and plans to elect optional expedients as reference rate reform activities occur. The Company does not expect the guidance to have a material impact~~such variable rates on its consolidated financial ~~statements or disclosures.~~statements.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(3) Revenue Recognition

Refer to Note 1. “Summary of Significant Accounting Policies” in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2020,~~2021, for the Company’s policies regarding ~~“Revenues”~~“Revenue” and “Accounts receivable, net.”

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

Disaggregation of ~~Revenues~~Revenue

Revenue by product type and market is set forth in the following tables. With respect to its seaborne mining 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 September 30, 2021													Three Months Ended September 30, 2022
		Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated			Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
		(Dollars in millions)													(Dollars in millions)
Thermal coal	Thermal coal													Thermal coal
Domestic	Domestic	$	41.1	$	—	$	247.3	$	181.0	$	—	$	469.4	Domestic	$	44.8	$	—	$	290.2	$	259.8	$	—	$	594.8
Export	Export	219.4		—		—		2.2		—		221.6		Export	308.3		—		—		—		—		308.3
Total thermal	Total thermal	260.5		—		247.3		183.2		—		691.0		Total thermal	353.1		—		290.2		259.8		—		903.1
Metallurgical coal	Metallurgical coal													Metallurgical coal

Export	Export	—		176.8		—		—		—		176.8		Export	—		309.9		—		—		—		309.9
Total metallurgical	Total metallurgical	—		176.8		—		—		—		176.8		Total metallurgical	—		309.9		—		—		—		309.9
Other (2)	Other (2)	0.2		2.7		(0.2)		1.4		(192.9)		(188.8)		Other (2)	0.1		0.8		0.3		1.6		126.7		129.5
Revenues		$	260.7	$	179.5	$	247.1	$	184.6	$	(192.9)	$	679.0
Revenue														Revenue	$	353.2	$	310.7	$	290.5	$	261.4	$	126.7	$	1,342.5

Three Months Ended September 30, 2020
Seaborne Thermal Mining Seaborne Metallurgical Mining Powder River Basin Mining Other U.S. Thermal Mining
Corporate and Other (1)
Consolidated
(Dollars in millions)
Thermal coal
Domestic $ 37.1 $ — $ 264.3 $ 172.8 $ — $ 474.2
Export 125.7 — — — — 125.7
Total thermal 162.8 — 264.3 172.8 — 599.9
Metallurgical coal
Export — 78.4 — — — 78.4
Total metallurgical — 78.4 — — — 78.4
Other (2)
0.2 0.4 0.5 7.0 (15.4) (7.3)
Revenues $ 163.0 $ 78.8 $ 264.8 $ 179.8 $ (15.4) $ 671.0


		Nine Months Ended September 30, 2021													Three Months Ended September 30, 2021
		Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated			Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
		(Dollars in millions)													(Dollars in millions)
Thermal coal	Thermal coal													Thermal coal
Domestic	Domestic	$	132.7	$	—	$	724.5	$	487.8	$	—	$	1,345.0	Domestic	$	41.1	$	—	$	247.3	$	181.0	$	—	$	469.4
Export	Export	497.7		—		—		3.4		—		501.1		Export	219.4		—		—		2.2		—		221.6
Total thermal	Total thermal	630.4		—		724.5		491.2		—		1,846.1		Total thermal	260.5		—		247.3		183.2		—		691.0
Metallurgical coal	Metallurgical coal													Metallurgical coal
Domestic		—		2.7		—		—		—		2.7

Export	Export	—		381.1		—		—		—		381.1		Export	—		176.8		—		—		—		176.8
Total metallurgical	Total metallurgical	—		383.8		—		—		—		383.8		Total metallurgical	—		176.8		—		—		—		176.8
Other (2)	Other (2)	0.8		4.2		(0.4)		4.8		(185.6)		(176.2)		Other (2)	0.2		2.7		(0.2)		1.4		(192.9)		(188.8)
Revenues		$	631.2	$	388.0	$	724.1	$	496.0	$	(185.6)	$	2,053.7
Revenue														Revenue	$	260.7	$	179.5	$	247.1	$	184.6	$	(192.9)	$	679.0

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)


		Nine Months Ended September 30, 2020													Nine Months Ended September 30, 2022
		Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated			Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
		(Dollars in millions)													(Dollars in millions)
Thermal coal	Thermal coal													Thermal coal
Domestic	Domestic	$	111.9	$	—	$	736.7	$	501.5	$	—	$	1,350.1	Domestic	$	125.0	$	—	$	771.6	$	682.5	$	—	$	1,579.1
Export	Export	412.9		—		—		—		—		412.9		Export	833.7		—		—		1.0		—		834.7
Total thermal	Total thermal	524.8		—		736.7		501.5		—		1,763.0		Total thermal	958.7		—		771.6		683.5		—		2,413.8
Metallurgical coal	Metallurgical coal													Metallurgical coal

Export	Export	—		362.3		—		—		—		362.3		Export	—		1,161.2		—		—		—		1,161.2
Total metallurgical	Total metallurgical	—		362.3		—		—		—		362.3		Total metallurgical	—		1,161.2		—		—		—		1,161.2
Other (2)	Other (2)	1.3		1.3		0.5		22.6		(7.1)		18.6		Other (2)	0.6		4.6		(0.2)		5.9		(230.1)		(219.2)
Revenues		$	526.1	$	363.6	$	737.2	$	524.1	$	(7.1)	$	2,143.9
Revenue														Revenue	$	959.3	$	1,165.8	$	771.4	$	689.4	$	(230.1)	$	3,355.8


	Nine Months Ended September 30, 2021
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	132.7	$	—	$	724.5	$	487.8	$	—	$	1,345.0
Export	497.7		—		—		3.4		—		501.1
Total thermal	630.4		—		724.5		491.2		—		1,846.1
Metallurgical coal


Export	—		383.8		—		—		—		383.8
Total metallurgical	—		383.8		—		—		—		383.8
Other (2)	0.8		4.2		(0.4)		4.8		(185.6)		(176.2)
Revenue	$	631.2	$	388.0	$	724.1	$	496.0	$	(185.6)	$	2,053.7

(1) Corporate and Other ~~revenue~~ includes ~~net losses related to unrealized mark-to-market adjustments on derivatives related to forecasted sales and other financial trading activity of $238.4 million and $16.1 million during~~ the three months ended September 30, 2021 and 2020, respectively, and $263.2 million and $13.7 million during the nine months ended September 30, 2021 and 2020, respectively. Refer to Note 7. “Derivatives and Fair Value Measurements” for additional information. Also included in Corporate and Other revenue are revenues with customers of $55.5 million and $97.3 million during the three and nine months ended September 30, 2021, respectively, and ($13.0) million and ($32.1) million during the three and nine months ended September 30, 2020, respectively.following:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Unrealized gains (losses) on derivative contracts related to forecasted sales	$	90.4	$	(238.4)	$	(235.1)	$	(264.0)
Realized losses on derivative contracts related to forecasted sales	(117.4)		(13.1)		(308.0)		(28.1)
Revenue from physical sale of coal (3)	150.7		56.9		294.0		98.0
Trading revenue	0.3		0.7		10.7		1.4
Other (2)	2.7		1.0		8.3		7.1
Total Corporate and Other	$	126.7	$	(192.9)	$	(230.1)	$	(185.6)

(2) ~~Other includes revenues~~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 and property and facility rentals.

~~The Company recorded~~(3) Includes revenue ~~related to delivered~~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 ~~approximately $923 million and $665 million during~~settling certain derivative contracts. Primarily represents the ~~three months ended September 30, 2021 and 2020, respectively, and approximately $2,327 million and $2,093 million during~~difference between the nine months ended September 30, 2021 and 2020, respectively. Such amounts exclude unrealized and realized gains and losses on derivative contracts related to forecasted sales and certain other revenues unrelated to delivered coal.

~~Committed Revenue from Contracts~~price contracted with ~~Customers~~

The Company expects to recognize revenue subsequent to September 30, 2021 of approximately $4.6 billion related to contracts with customers in which volumes and prices per ton were fixed or reasonably estimable at September 30, 2021. Approximately 42% of such amount is expected to be recognized over the ~~next twelve months~~customer and the ~~remainder thereafter. Actual revenue related~~price allocated to such contracts may differ materially for various reasons, including price adjustment features for coal quality and cost escalations, volume optionality provisions and potential force majeure events. This estimate of future revenue does not include any revenue related to contracts with variable prices per ton that cannot be reasonably estimated, such as the ~~majority of seaborne metallurgical and seaborne thermal coal contracts where pricing is negotiated or settled quarterly or annually.~~

~~Accounts Receivable~~

~~“Accounts receivable, net” at September 30, 2021 and December 31, 2020 consisted of the following:~~

September 30, 2021 December 31, 2020
(Dollars in millions)
Trade receivables, net $ 237.2 $ 180.9
Miscellaneous receivables, net 38.8 63.9
Accounts receivable, net $ 276.0 $ 244.8

Trade receivables, net included no allowance for credit losses as of both September 30, 2021 and December 31, 2020. Miscellaneous receivables, net included no allowance for credit losses as of both September 30, 2021 and December 31, 2020. Charges for credit losses of less than $0.1 million were recognized during the nine months ended September 30, 2021. NaN charges for credit losses were recognized during the three months ended September 30, 2021 and 2020 or during the nine months ended September 30, 2020.operating segment.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

~~(4) Discontinued Operations~~

Discontinued operations include certain former Seaborne Thermal Mining and Other U.S. Thermal Mining segment assets that have ceased production and other previously divested legacy operations, including Patriot Coal Corporation and certain of its wholly-owned subsidiaries (Patriot). In the third quarter of 2021, the Company executed the sale of the closed Wilkie Creek Mine, which reduced its closed mine reclamation liabilities and associated costs. Refer to Note 14. “Other Events” for additional information associated with the Company’s sale of the Wilkie Creek Mine.

~~Summarized Results of Discontinued Operations~~

~~Results from discontinued operations were as follows during the periods presented below:~~

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Income (loss) from discontinued operations, net of income taxes $ 24.3 $ (2.3) $ 20.0 $ (6.8)

~~Liabilities of Discontinued Operations~~

~~Liabilities classified as discontinued operations included in the Company’s condensed consolidated balance sheets were as follows:~~

September 30, 2021 December 31, 2020
(Dollars in millions)
Liabilities:
Accounts payable and accrued expenses $ 43.8 $ 62.3
Other noncurrent liabilities 66.0 91.4
Total liabilities classified as discontinued operations $ 109.8 $ 153.7

~~Patriot-Related Matters~~

A significant portion of the liabilities in the table above relate to 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 (UMWA), 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 in the U.S. District Court for the Eastern District of Virginia 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 2 different buyers.

~~Black Lung Occupational Disease Liabilities.~~ 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.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

“Accounts receivable, net” at September 30, ~~2021~~2022 and December 31, ~~2020, respectively. 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~~2021 consisted of the ~~Company’s recorded liability reflects only Patriot workers employed by former subsidiaries~~following:


	September 30, 2022		December 31, 2021
	(Dollars in millions)
Trade receivables, net	$	387.1	$	307.0
Miscellaneous receivables, net	39.3		43.5
Accounts receivable, net	$	426.4	$	350.5

None of the ~~Company that are presently retired, disabled~~above receivables included allowances for credit losses at September 30, 2022 or ~~otherwise not actively employed. The Company cannot reliably estimate~~December 31, 2021. No charges for credit losses were recognized during 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.three and nine months ended September 30, 2022 or 2021.

~~(5)~~(4) Inventories

“Inventories, net” as of September 30, ~~2021~~2022 and December 31, ~~2020~~2021 consisted of the following:


		September 30, 2021		December 31, 2020			September 30, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Materials and supplies		$	98.3	$	102.6
Materials and supplies, net						Materials and supplies, net	$	121.7	$	102.1
Raw coal	Raw coal	53.5		70.5		Raw coal	58.5		54.6
Saleable coal	Saleable coal	72.7		88.5		Saleable coal	97.2		70.0
Total		$	224.5	$	261.6
Inventories, net						Inventories, net	$	277.4	$	226.7

Materials and supplies inventories, net presented above have been shown net of reserves of ~~$9.8~~$7.6 million and ~~$10.4~~$9.0 million as of September 30, ~~2021~~2022 and December 31, ~~2020, respectively.~~2021.

~~(6)~~(5) Equity Method Investments

The Company had total equity method investments and financing receivables of ~~$26.8~~$32.8 million and ~~$24.6~~$62.2 million reflected in “Investments and other assets” in the condensed consolidated balance sheets as of September 30, ~~2021~~2022 and December 31, ~~2020,~~2021, respectively, related to Middlemount Coal Pty Ltd (Middlemount). Included in ~~“(Income) loss~~“Income from equity affiliates” in the unaudited condensed consolidated statements of operations ~~were gains~~was income related to Middlemount of $28.4 million and $15.8 million during the three months ended September 30, 2022 and 2021, respectively, and $123.6 million and $11.4 million during the ~~three and~~ nine months ended September 30, ~~2021, respectively,~~2022 and ~~losses of $10.6 million and $25.7 million during the three and nine months ended September 30, 2020,~~2021, respectively.

The Company received cash payments from Middlemount of $151.5 million and $7.6 million during the nine months ended September 30, ~~2021. No payments were received from from Middlemount during the nine months ended September 30, 2020.~~2022 and 2021, respectively.

One of the Company’s Australian subsidiaries ~~and the other shareholder of Middlemount are parties~~is party to an agreement ~~as amended from time to time,~~ to provide a revolving loan ~~(Revolving Loans)~~ to Middlemount. The ~~Company’s~~Company’s participation in the ~~Revolving Loans~~revolving loan will not, at any time, exceed its 50% equity interest of the revolving loan ~~limit. At~~limit, which was $50 million Australian dollars at September 30, ~~2021, the~~2022. The revolving loan ~~limit was~~ ~~$160 million~~ ~~Australian dollars and the Revolving Loans were not fully drawn upon by Middlemount. The Revolving Loans bear~~bears interest at 10% per annum and ~~expire~~expires on December 31, ~~2021. The value of the portion of the Revolving Loans due to the Company’s Australian subsidiary~~ 2023. There was ~~$35.7 million and~~ ~~$46.2 million as of~~no outstanding revolving loan at September 30, ~~2021 and~~ 2022 or December 31, ~~2020, respectively, with the decrease during the nine months ended September 30, 2021 primarily attributable to payments made by Middlemount.~~2021.

~~As of both~~ ~~September 30, 2021 and December 31, 2020, the financing receivables and Revolving Loans are~~ ~~accounted for as in-substance common stock due to the limited fair value attributed to Middlemount’s equity.~~

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

~~(7)~~(6) Derivatives and Fair Value Measurements

Derivatives

From time to time, the Company may utilize various types of derivative instruments to manage its exposure to risks in the normal course of business, including (1) foreign currency exchange rate risk and the variability of cash flows associated with forecasted Australian dollar expenditures made in its Australian mining platform, (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.

Table of Contents

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 0no diesel fuel or interest rate derivatives in place as of September 30, ~~2021.~~2022.

Foreign Currency Option Contracts

As of September 30, ~~2021,~~2022, the Company had currency options outstanding with an aggregate notional amount of ~~$595.0~~$855.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending June 30, ~~2022.~~2023. The instruments are quarterly average rate options which 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 ~~$0.77~~$0.70 to ~~$0.81~~$0.80 over the nine-month period ending June 30, ~~2022.~~2023.

Derivative Contracts Related to Forecasted Sales

As of September 30, ~~2021,~~2022, the Company held coal derivative contracts related to a portion of its forecasted sales with an aggregate notional volume of ~~2.9~~1.0 million tonnes. Such financial contracts may include futures, forwards and options. Included in this total are ~~2.1~~0.9 million tonnes related to financial derivatives entered to support the profitability of the Wambo Underground Mine as part of a strategy to extend the mine life through mid-2023. Of this total, ~~1.4~~0.3 million tonnes will settle in 2022 and ~~0.7~~0.6 million tonnes will settle in ~~2023 at expected average pricing of approximately $84 per tonne (Newcastle index).~~2023. The remaining ~~0.8~~0.1 million tonnes aggregate notional volume related to other coal financial contracts will settle in ~~the fourth quarter of 2021 (0.2 million tonnes) and 2022 (0.6 million tonnes).~~2022. Additionally, 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 September 30, ~~2021,~~2022, the Company recorded ana net unrealized mark-to-market ~~loss~~gain of ~~$238.4~~$90.4 million on these coal derivative contracts, which includes approximately ~~$183~~$49 million of unrealized mark-to-market gains on financial derivatives and approximately $41 million of unrealized mark-to-market gains on physical forward sales contracts. During the nine months ended September 30, 2022, the Company recorded a net unrealized mark-to-market loss of $235.1 million on these coal derivative contracts, which includes approximately $257 million of unrealized mark-to-market losses on financial derivatives and approximately ~~$55~~$22 million of unrealized mark-to-market gains 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 September 30, ~~2021.~~

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

2022.

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.


		September 30, 2021				December 31, 2020 (1)					September 30, 2022				December 31, 2021
		Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative			Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative
		(Dollars in millions)									(Dollars in millions)
Foreign currency option contracts	Foreign currency option contracts	$	1.1	$	—	$	10.3	$	—	Foreign currency option contracts	$	1.4	$	—	$	1.4	$	—
Derivative contracts related to forecasted sales	Derivative contracts related to forecasted sales	113.0		(385.2)		16.7		(24.7)		Derivative contracts related to forecasted sales	236.0		(633.7)		59.5		(184.2)
Financial trading contracts	Financial trading contracts	1.5		—		0.4		—		Financial trading contracts	12.2		—		3.4		—
Total derivatives	Total derivatives	115.6		(385.2)		27.4		(24.7)		Total derivatives	249.6		(633.7)		64.3		(184.2)
Effect of counterparty netting	Effect of counterparty netting	(113.0)		113.0		(16.2)		16.2		Effect of counterparty netting	(236.0)		236.0		(59.5)		59.5
Variation margin (received) posted	Variation margin (received) posted	(1.5)		215.8		(0.3)		6.8		Variation margin (received) posted	(12.2)		390.0		(3.4)		95.2
Net derivatives and variation margin as classified in the balance sheets	Net derivatives and variation margin as classified in the balance sheets	$	1.1	$	(56.4)	$	10.9	$	(1.7)	Net derivatives and variation margin as classified in the balance sheets	$	1.4	$	(7.7)	$	1.4	$	(29.5)

~~(1)~~

Table of ContentsCertain comparative amounts have been reclassified to conform with the 2021 presentation. The reclassifications do not impact the prior year presentation of the accompanying condensed consolidated balance sheets.

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 September 30, ~~2021,~~2022, the Company had posted ~~$239.6~~$465.9 million aggregate margin cash, consisting of ~~$214.3~~$377.8 million variation margin cash and ~~$25.3~~$88.1 million initial margin. As of December 31, ~~2020,~~2021, the Company had posted ~~$9.5~~$130.1 million aggregate margin cash, consisting of ~~$6.5~~$91.8 million variation margin cash and ~~$3.0~~$38.3 million initial margin.

The net amount of asset derivatives, net of variation margin, ~~are~~is included in “Other current assets” and the net amount of liability derivatives, net of variation margin, ~~are~~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 ~~pre-tax~~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 September 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	$	(3.0)	$	(1.6)	$	(1.4)
Derivative contracts related to forecasted sales	Revenue	(27.0)		(117.4)		90.4
Financial trading contracts	Revenue	0.3		0.5		(0.2)
Total		$	(29.7)	$	(118.5)	$	88.8

		Three Months Ended September 30, 2021
		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	$	(1.0)	$	(1.6)	$	0.6
Derivative contracts related to forecasted sales	Revenue	(251.5)		(13.1)		(238.4)
Financial trading contracts	Revenue	0.7		0.7		—
Total		$	(251.8)	$	(14.0)	$	(237.8)

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Three Months Ended September 30, 2021
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 $ (1.0) $ (1.6) $ 0.6
Derivative contracts related to forecasted sales Revenues (251.5) (13.1) (238.4)
Financial trading contracts Revenues 0.7 0.7 —
Total $ (251.8) $ (14.0) $ (237.8)
Three Months Ended September 30, 2020 (1)
Total gain (loss) recognized in income Gain (loss) 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 $ 3.9 $ 3.2 $ 0.7
Derivative contracts related to forecasted sales Revenues (3.3) 12.8 (16.1)
Financial trading contracts Revenues (0.2) (0.2) —
Total $ 0.4 $ 15.8 $ (15.4)

Nine Months Ended September 30, 2021
Total (loss) gain recognized in income Gain (loss) 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 $ (5.3) $ 3.0 $ (8.3)
Derivative contracts related to forecasted sales Revenues (292.1) (28.1) (264.0)
Financial trading contracts Revenues 1.4 0.6 0.8
Total $ (296.0) $ (24.5) $ (271.5)
Nine Months Ended September 30, 2020 (1)
Total gain (loss) recognized in income 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 $ 1.6 $ 3.6
Derivative contracts related to forecasted sales Revenues 19.6 30.9 (11.3)
Financial trading contracts Revenues (0.5) 1.9 (2.4)
Total $ 24.3 $ 34.4 $ (10.1)

~~(1)~~ 2020 ‘gain/(loss) realized in income on derivatives’ has been revised to exclude revenues arising from coal deliveries earned by the Company’s trading and brokerage function of ($13.0) million and ($32.1) million for the three and nine month periods ending September 30, 2020, respectively, to be comparable to the presentation of the 2021 amounts.


		Nine Months Ended September 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	$	(8.2)	$	(3.8)	$	(4.4)
Derivative contracts related to forecasted sales	Revenue	(543.1)		(308.0)		(235.1)
Financial trading contracts	Revenue	10.7		0.6		10.1
Total		$	(540.6)	$	(311.2)	$	(229.4)

		Nine Months Ended September 30, 2021
		Total (loss) gain recognized in income		Gain (loss) 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	$	(5.3)	$	3.0	$	(8.3)
Derivative contracts related to forecasted sales	Revenue	(292.1)		(28.1)		(264.0)
Financial trading contracts	Revenue	1.4		0.6		0.8
Total		$	(296.0)	$	(24.5)	$	(271.5)

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

~~Table of Contents~~

~~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.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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


		September 30, 2021									September 30, 2022
		Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total
		(Dollars in millions)									(Dollars in millions)
Foreign currency option contracts	Foreign currency option contracts	$	—	$	1.1	$	—	$	1.1	Foreign currency option contracts	$	—	$	1.4	$	—	$	1.4
Derivative contracts related to forecasted sales	Derivative contracts related to forecasted sales	—		(272.2)		—		(272.2)		Derivative contracts related to forecasted sales	—		(397.7)		—		(397.7)
Financial trading contracts	Financial trading contracts	—		1.5		—		1.5		Financial trading contracts	—		12.2		—		12.2
Equity securities	Equity securities	—		—		4.0		4.0		Equity securities	—		—		2.3		2.3
Total net (liabilities) assets	Total net (liabilities) assets	$	—	$	(269.6)	$	4.0	$	(265.6)	Total net (liabilities) assets	$	—	$	(384.1)	$	2.3	$	(381.8)

		December 31, 2020 (1)									December 31, 2021
		Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total
		(Dollars in millions)									(Dollars in millions)
Foreign currency option contracts	Foreign currency option contracts	$	—	$	10.3	$	—	$	10.3	Foreign currency option contracts	$	—	$	1.4	$	—	$	1.4
Derivative contracts related to forecasted sales	Derivative contracts related to forecasted sales	—		(7.9)		—		(7.9)		Derivative contracts related to forecasted sales	—		(124.7)		—		(124.7)
Financial trading contracts	Financial trading contracts	—		0.4		—		0.4		Financial trading contracts	—		3.4		—		3.4
Equity securities	Equity securities	—		—		4.0		4.0		Equity securities	—		—		4.0		4.0
Total net assets		$	—	$	2.8	$	4.0	$	6.8
Total net (liabilities) assets										Total net (liabilities) assets	$	—	$	(119.9)	$	4.0	$	(115.9)

~~(1)~~ December 31, 2020 ‘total net assets’ has been revised to exclude $6.5 million variation margin cash for comparability to 2021 presentation. Variation margin cash was $214.3 million as of September 30, 2021.

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

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

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

•Investments in equity securities are based on observed prices in an inactive market (Level 3).

Other Financial Instruments. The following methods and assumptions were used by the Company in estimating fair values for other financial instruments as of September 30, ~~2021~~2022 and December 31, ~~2020:~~2021:

•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).

1514

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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.


		September 30, 2021		December 31, 2020			September 30, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Total debt at par value	Total debt at par value	$	1,373.8	$	1,591.3	Total debt at par value	$	891.0	$	1,173.2
Less: Unamortized debt issuance costs and original issue discount	Less: Unamortized debt issuance costs and original issue discount	(45.6)		(43.5)		Less: Unamortized debt issuance costs and original issue discount	(21.8)		(35.4)
Net carrying amount	Net carrying amount	$	1,328.2	$	1,547.8	Net carrying amount	$	869.2	$	1,137.8

Estimated fair value	Estimated fair value	$	1,236.3	$	987.6	Estimated fair value	$	1,034.0	$	1,136.5

Generally, the Company’s Level 3 instruments or contracts are valued using bid/ask price quotations and other market assessments obtained from multiple, independent third-party brokers or other transactional data incorporated into internally-generated discounted cash flow models. Decreases in the number of third-party brokers or market liquidity could erode the quality of market information and therefore the valuation of the Company’s market positions. The Company’s valuation techniques include basis adjustments to the foregoing price inputs for quality, such as sulfur and ash content, location differentials, expressed as port and freight costs, and credit risk. The Company’s risk management function ~~which is independent of~~independently validates the Company’s ~~coal trading function,~~valuation inputs, including unobservable inputs, with third-party information and settlement prices from other sources where available. A daily process is ~~responsible~~performed to analyze market price changes and changes to the portfolio. Further periodic validation occurs at the time contracts are settled with the counterparty. These valuation techniques have been consistently applied in all periods presented, and the Company believes it has obtained the most accurate information available for ~~valuation policies and procedures, with oversight from executive management. The~~the types of derivative contracts held.

Significant increases or decreases in the inputs in isolation could result in a significantly higher or lower fair value ~~of the Company’s coal derivative assets and liabilities reflects adjustments for credit risk.~~measurement. The ~~Company’s exposure is substantially~~unobservable inputs do not have a direct interrelationship; therefore, a change in one unobservable input would not necessarily correspond with ~~electric utilities, energy marketers, steel producers and nonfinancial trading houses.~~a change in another unobservable input.

The Company had no transfers between Levels 1, 2 and 3 during the three and nine months ended September 30, ~~2021~~2022 and ~~2020.~~2021. The Company’s policy is to value all transfers between levels using the beginning of period valuation. The Company recorded an impairment loss of $1.7 million related to its Level 3 investment in equity securities during the three months ended September 30, 2022.

~~(8)~~(7) Property, Plant, Equipment and Mine Development

The composition of property, plant, equipment and mine development, net, as of September 30, ~~2021~~2022 and December 31, ~~2020~~2021 is set forth in the table below:


		September 30, 2021		December 31, 2020			September 30, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Land and coal interests	Land and coal interests	$	2,470.9	$	2,482.9	Land and coal interests	$	2,487.3	$	2,494.1
Buildings and improvements	Buildings and improvements	543.6		481.0		Buildings and improvements	596.1		550.8
Machinery and equipment	Machinery and equipment	1,436.0		1,408.5		Machinery and equipment	1,440.0		1,386.2
Less: Accumulated depreciation, depletion and amortization	Less: Accumulated depreciation, depletion and amortization	(1,498.5)		(1,321.3)		Less: Accumulated depreciation, depletion and amortization	(1,705.8)		(1,480.5)
Property, plant, equipment and mine development, net	Property, plant, equipment and mine development, net	$	2,952.0	$	3,051.1	Property, plant, equipment and mine development, net	$	2,817.6	$	2,950.6

Asset Impairment and Other At-Risk Assets

During the nine months ended September 30, 2020, the Company recognized an asset impairment charge of $1,418.1 million related to its North Antelope Rochelle Mine of the Powder River Basin Mining segment. Of this amount, $1,393.7 million related to the property, plant, equipment and mine development assets; $19.9 million related to operating lease right-of-use assets; and $4.5 million related to contract-based intangible assets. The outlook for the mine was negatively impacted by the accelerated decline of coal-fired electricity generation in the U.S., driven by the reduced utilization of plants and plant retirements, sustained low natural gas pricing and the increased use of renewable energy sources. These factors led to the expectation of reduced future sales volumes. The impairment charge was based upon the remaining estimated discounted cash flows of the mine. Such cash flows were based upon estimates which generally constitute unobservable Level 3 inputs under the fair value hierarchy, including, but not limited to, future tons sold, coal prices for unpriced coal, production costs (including costs for labor, commodity supplies and contractors), transportation costs and a risk-adjusted, cost of capital.

~~No asset impairment charges were recorded during the three and nine months ended September 30, 2021 or the three months ended September 30, 2020.~~

The Company has identified certain assets with an aggregate carrying value of ~~approximately $1.1 billion~~$209.2 million at September 30, ~~2021~~2022 in its ~~Seaborne Metallurgical Mining, Powder River Basin Mining,~~ Other U.S. Thermal Mining ~~and Corporate and Other segments~~segment whose recoverability is most sensitive to ~~coal pricing, cost pressures,~~ customer demand, customer concentration risk and future economic viability. The Company conducted a review of those assets as of September 30, ~~2021~~2022 and determined that no impairment charges were necessary as of that date.

1615

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~(9) Leases~~(8) Income Taxes

The ~~Company has operating and finance leases~~Company's effective tax rate before remeasurement for ~~mining and non-mining equipment, office space and certain other facilities under various non-cancellable agreements. Historically,~~ the majority of the Company’s leases have been accounted for as operating leases. 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, 2020, for the Company’s policies regarding “Leases.”

The Company and certain of its subsidiaries have guaranteed other subsidiaries’ performance under various lease obligations. Certain lease agreements are subject to the restrictive covenants of the Company’s credit facilities and include cross-acceleration provisions, under which the lessor could require remedies including, but not limited to, immediate recovery of the present value of any remaining lease payments. The Company typically agrees to indemnify lessors for the value of the property or equipment leased, should the property be damaged or lost during the course of the Company’s operations. The Company expects that losses with respect to leased property, if any, may be covered by insurance (subject to deductibles). Aside from indemnification of the lessor for the value of the property leased, the Company’s maximum potential obligations under its leases are equal to the respective future minimum lease payments, and the Company assumes that no amounts could be recovered from third parties.

~~The components of lease expense during the three and~~ nine months ended September 30, 2022 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 is expecting to utilize substantial net operating losses in Australia and the U.S. in 2022 based on estimated pretax income. The Company’s income tax provision of $10.7 million and income tax benefit of $3.7 million for the three months ended September 30, 2022 and 2021, respectively, included tax benefits of $1.6 million and ~~2020 were~~$1.1 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax provision of $21.0 million and income tax benefit of $10.3 million for the nine months ended September 30, 2022 and 2021, respectively, included tax benefits of $3.5 million and $1.6 million, respectively, related to the remeasurement of foreign income tax accounts.

(9) Long-term Debt

The Company’s total indebtedness as ~~follows:~~of September 30, 2022 and December 31, 2021 consisted of the following:

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Operating lease cost:
Operating lease cost $ 4.6 $ 6.3 $ 15.3 $ 23.3
Short-term lease cost 4.1 10.2 10.5 31.7
Variable lease cost 1.0 1.1 2.0 3.7
Sublease income (0.5) — (1.5) —
Total operating lease cost $ 9.2 $ 17.6 $ 26.3 $ 58.7
Finance lease cost:
Amortization of right-of-use assets $ 1.6 $ 0.8 $ 3.7 $ 5.2
Interest on lease liabilities 0.8 0.2 2.0 0.5
Total finance lease cost $ 2.4 $ 1.0 $ 5.7 $ 5.7


Debt Instrument (defined below, as applicable)	September 30, 2022		December 31, 2021
	(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	—	$	23.1
8.500% Senior Secured Notes due December 2024 (2024 Peabody Notes)	—		62.6
10.000% Senior Secured Notes due December 2024 (2024 Co-Issuer Notes)	81.6		193.9
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	114.6		206.0
6.375% Senior Secured Notes due March 2025 (2025 Notes)	66.2		334.9
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	282.6		322.8
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	320.0		—


Finance lease obligations	25.7		29.3
Less: Debt issuance costs	(21.5)		(34.8)
	869.2		1,137.8
Less: Current portion of long-term debt (1)	546.9		59.6
Long-term debt	$	322.3	$	1,078.2

(1) The Company has the positive intent and ability to retire additional debt in the next twelve months using working capital. As such, all debt with the exception of the 2028 Convertible Notes and finance lease obligations was classified within “Current portion of long-term debt” in the accompanying condensed consolidated balance sheets at September 30, 2022.

2021 Financing Activity and Subsequent Debt Repurchases

During the first quarter of 2021, the Company completed a series of financing transactions to provide the Company with maturity extensions and covenant relief, while allowing it to maintain near-term operating liquidity. These transactions included a senior notes exchange, a revolving credit facility exchange, various amendments to the Company’s existing debt agreements, and a support agreement with the Company’s surety bond providers.

Subsequent to these transactions, the Company completed additional financing transactions during 2021 which included the implementation of an at-the-market equity offering program pursuant to which the Company sold approximately 24.8 million shares of common stock for net cash proceeds of $269.8 million, the retirement of $270.9 million principal amount of existing debt through various open market purchases at an aggregate cost of $232.4 million, and the issuance of an aggregate 10.0 million shares of common stock in exchange for an additional $106.1 million principal amount of existing debt through multiple bilateral transactions with debt holders.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

In the event of open market purchases of its debt, the terms of the 2024 Peabody Notes - now redeemed as described below - required, and the letter of credit facility entered into by the Company in connection with the 2021 financing activity (Company LC Agreement) requires the Company to make repurchase offers to those debt and lien holders. In general, the repurchase offers equate to 25% of the principal amount of priority lien debt repurchased in the preceding quarter at a price equal to the weighted average repurchase price paid over that quarter. The open market debt repurchases completed during the three months ended December 31, 2021 necessitated a mandatory repurchase offer of up to $38.6 million of 2024 Peabody Notes, at 94.94% of their aggregate accreted value, plus accrued and unpaid interest, and a concurrent repurchase offer of priority lien obligations under the Company LC Agreement. The offer resulted in the valid tender and purchase of $0.1 million aggregate accreted value of 2024 Peabody Notes and $30.0 million aggregate principal and commitment amounts under the Company LC Agreement during the three months ended March 31, 2022. The Company’s purchase of the principal and commitment amounts under the Company LC Agreement was effected by the posting of $28.5 million of collateral with the administrative agent and did not reduce the availability under the facility. During the three months ended September 30, 2022, the Company repurchased $48.8 million aggregate principal amount of its Senior Secured Term Loan and 2025 Notes for $46.6 million in various open market transactions. As a result of these repurchases, the Company made a mandatory offer to repurchase $12.2 million of priority lien obligations under the Company LC Agreement at 95.57% on October 17, 2022. The offer will expire on November 16, 2022.

The 2024 Co-Issuer Notes and the Co-Issuer Term Loans are also subject to mandatory prepayment offers at the end of each six-month period, beginning with June 30, 2021, whereby the Excess Cash Flow (as defined in the 2024 Co-Issuer Notes indenture) generated by the Wilpinjong Mine during each such period may be applied to the principal of such notes and loans on a pro rata basis, provided that the liquidity attributable to the Wilpinjong Mine would not fall below $60.0 million. Such prepayments may be accepted or declined at the option of the debt holders. Based upon the Wilpinjong Mine’s results for the six-month period ended December 31, 2021, a required offer to prepay $105.6 million of total principal resulted in the prepayment of $17.2 million of Co-Issuer Term Loans principal and $0.3 million of 2024 Co-Issuer Notes principal during the three months ended March 31, 2022. Based upon the Wilpinjong Mine’s results for the six-month period ended June 30, 2022, the Company offered to prepay $65.1 million of total principal at 103.91% during the three months ended September 30, 2022. The holders of the Co-Issuer Term Loans unanimously declined their $37.9 million pro rata portion of the offer and the holders of the 2024 Co-Issuer Notes tendered for prepayment $18.2 million principal amount of their $27.2 million pro rata portion of the offer. The Company completed the prepayment during the three months ended September 30, 2022.

Voluntary repurchases of Co-Issuer Term Loans are permissible through various methods, including a modified Dutch auction process in which the Company may solicit acceptable prices from holders. During the three months ended June 30, 2022, the Company solicited bids from all holders of Co-Issuer Term Loans for the repurchase of up to $50.0 million principal amount, resulting in that full amount of principal being repurchased at a weighted average price of 103.91%, or $52.0 million in total. During the three months ended September 30, 2022, the Company solicited bids from all holders of Co-Issuer Term Loans for the repurchase of up to $75.0 million principal amount, resulting in $20.4 million of principal being repurchased at a weighted average price of 105.91%, or $21.6 million in total.

The indenture which governs the 2024 Co-Issuer Notes requires that, within 30 business days following a repurchase of the Co-Issuer Term Loans such as that undertaken through the auction processes described above, the Company must also offer to repurchase an equivalent principal amount of the 2024 Co-Issuer Notes at the equivalent purchase price. Further, the credit agreement which governs the Co-Issuer Term Loans requires parity between the holders of Co-Issuer Term Loans and holders of the 2024 Co-Issuer Notes with respect to repurchase offers. As a result of the modified Dutch auction process completed during the three months ended June 30, 2022, the required equivalent offer to purchase $50.0 million aggregate principal amount of 2024 Co-Issuer Notes was made by the Company on May 26, 2022 and was subsequently increased to $93.9 million, at the Company’s discretion. The offer was fully tendered and the Company completed the repurchase on July 25, 2022 for $97.5 million. The discretionary increase to the 2024 Co-Issuer Notes repurchase offer compelled the Company to offer to repurchase an additional $43.9 million principal amount of Co-Issuer Term Loans at 103.91% which resulted in the valid tender and purchase of $3.8 million principal for $4.0 million during the three months ended September 30, 2022.

As a result of the modified Dutch auction process completed during the three months ended September 30, 2022, the Company offered to repurchase the outstanding $81.6 million principal amount of 2024 Co-Issuer Notes at 105.91% on September 19, 2022, which exceeded the required offer amount. To maintain parity with respect to the holders of the Co-Issuer Term Loans, the Company simultaneously offered to repurchase $61.2 million principal amount of Co-Issuer Term Loans at 105.91%. Both offers will expire on November 18, 2022.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~Supplemental balance sheet information related to leases at September 30, 2021~~The Company’s various debt repurchases during 2022 resulted in the realization of net losses from early debt extinguishment of $8.7 million and ~~December 31, 2020 was as follows:~~

September 30, 2021 December 31, 2020
(Dollars in millions)
Operating leases:
Operating lease right-of-use assets $ 38.4 $ 49.9
Accounts payable and accrued expenses $ 17.0 $ 24.5
Operating lease liabilities, less current portion 31.6 42.1
Total operating lease liabilities $ 48.6 $ 66.6
Finance leases:
Property, plant, equipment and mine development $ 31.3 $ 20.4
Accumulated depreciation (5.8) (2.5)
Property, plant, equipment and mine development, net $ 25.5 $ 17.9
Current portion of long-term debt $ 15.5 $ 21.5
Long-term debt, less current portion 14.9 5.8
Total finance lease liabilities $ 30.4 $ 27.3
Weighted average remaining lease term (years)
Operating leases 3.1
Finance leases 6.7
Weighted average discount rate
Operating leases 6.8 %
Finance leases 8.8 %

~~Supplemental cash flow information related to leases~~$11.5 million during the three months and nine months ended September 30, ~~2021~~2022, respectively.

3.250% Convertible Senior Notes due 2028

On March 1, 2022, through a private offering, the Company issued $320.0 million in aggregate principal amount of 3.250% Convertible Senior Notes due 2028 (the 2028 Convertible Notes). The 2028 Convertible Notes are senior unsecured obligations of the Company and ~~2020~~are governed under an indenture.

The Company used the proceeds of the offering of the 2028 Convertible Notes to redeem the remaining $62.6 million of its outstanding 2024 Peabody Notes and, together with available cash, approximately $257.4 million of its outstanding 2025 Notes, and to pay related premiums, fees and expenses relating to the offering of the 2028 Convertible Notes and the 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 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.

The 2028 Convertible Notes are convertible at the option of the holders only in the following circumstances: (1) during any calendar quarter commencing after the calendar quarter ended June 30, 2022, if the last reported sale price per share of the Company’s common stock exceeds 130% of the conversion price for each of at least 20 trading days during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter; (2) during the five consecutive business days immediately after any five consecutive trading day period (such five consecutive trading day period, the Measurement Period) in which the trading price per $1,000 principal amount of 2028 Convertible Notes for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price per share of the Company’s common stock on such trading day and the conversion rate on such trading day; (3) upon the occurrence of certain corporate events or distributions on the Company’s common stock; (4) if the Company calls any 2028 Convertible Notes for redemption; and (5) at any time from, and including, September 1, 2027 until the close of business on the second scheduled trading day immediately before the maturity date.

Upon conversion, the Company may satisfy its conversion obligation by paying or delivering, as ~~follows:~~applicable, cash, shares of the Company’s common stock or a combination of cash and shares of the Company’s common stock, at the Company’s election, in the manner and subject to the terms and conditions provided in the indenture. The initial conversion rate for the 2028 Convertible Notes will be 50.3816 shares of the Company’s common stock per $1,000 principal amount of 2028 Convertible Notes, which represents an initial conversion price of approximately $19.85 per share of the Company’s common stock. The initial conversion price represents a premium of approximately 32.5% to the $14.98 per share closing price of the Company’s common stock on February 24, 2022. The conversion rate is subject to adjustment under certain circumstances in accordance with the terms of the indenture. If certain corporate events described in the indenture occur prior to the maturity date, or the Company delivers a notice of redemption (as described below), the conversion rate will be increased for a holder who elects to convert its 2028 Convertible Notes in connection with such corporate event or notice of redemption, as the case may be, in certain circumstances.

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases $ 4.7 $ 6.8 $ 17.6 $ 26.4
Operating cash flows for finance leases 1.1 0.1 2.9 0.5
Financing cash flows for finance leases 2.8 0.2 5.6 8.1
Right-of-use assets obtained in exchange for lease obligations:
Operating leases — 0.2 6.8 2.3
Finance leases 1.1 0.5 21.3 1.5
The Company may not redeem the 2028 Convertible Notes prior to March 1, 2025. The Company may redeem for cash all or any portion of the 2028 Convertible Notes, at its option, on or after March 1, 2025 and on or before the 40th scheduled trading day immediately before the maturity date, at a cash redemption price equal to 100% of the principal amount of the 2028 Convertible Notes to be redeemed, plus accrued and unpaid interest, if any, to, but excluding, the redemption date, but only if the last reported sale price per share of the Company’s common stock exceeds 130% of the conversion price on (1) each of at least 20 trading days, whether or not consecutive, during the 30 consecutive trading days ending on, and including, the trading day immediately before the date the Company sends the related redemption notice; and (2) the trading day immediately before the date the Company sends such notice. However, the Company may not redeem less than all of the outstanding 2028 Convertible Notes unless at least $75 million aggregate principal amount of 2028 Convertible Notes are outstanding and not called for redemption as of the time the Company sends the related redemption notice. No sinking fund is provided for the 2028 Convertible Notes.

If the Company undergoes a fundamental change (as defined in the indenture), noteholders may require the Company to repurchase their 2028 Convertible Notes at a cash repurchase price equal to 100% of the principal amount of the 2028 Convertible Notes to be repurchased, plus accrued and unpaid interest, if any, to, but excluding, the fundamental change repurchase date.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Margin Financing Arrangement

On March 7, 2022, the Company entered into a credit agreement, by and among the Company, as borrower, Goldman Sachs Lending Partners LLC, as administrative agent, and the lenders party thereto (the Credit Agreement). The ~~Company's leases have remaining lease terms ranging from less than~~Credit Agreement provided for a $150 million unsecured revolving credit facility (the Revolving Facility), was scheduled to mature on April 1, ~~year~~2025 and bore interest at a rate of 10.0% per annum on drawn amounts. The Revolving Facility was intended to ~~20.3 years, and may include options to extend the terms, as applicable. The contractual maturities of lease liabilities were as follows:~~

Period Ending December 31, Operating Leases Finance Leases
(Dollars in millions)
2021 $ 6.6 $ 2.8
2022 18.4 11.1
2023 16.8 5.6
2024 6.0 4.7
2025 3.4 4.5
2026 and thereafter 3.8 9.5
Total lease payments 55.0 38.2
Less imputed interest (6.4) (7.8)
Total lease liabilities $ 48.6 $ 30.4

~~(10) Income Taxes~~

~~The Company's effective tax rate before remeasurement for the nine months ended September 30, 2021 is based on~~support the Company’s ~~estimated full year effective tax rate, comprised~~near-term liquidity requirements, particularly with respect to the cash margin requirements associated with the Company’s coal derivative contracts, which fluctuate depending upon underlying market coal prices. Concurrently with the Credit Agreement, the Company entered into an agreement with Goldman Sachs & Company LLC to act as sales agent for at-the-market equity offerings of ~~expected statutory tax provision, offset by foreign rate differential and changes in valuation allowance. The~~up to $225.0 million of the Company’s ~~income tax benefit of $3.7 million and $0.1 million for~~common stock.

During the three months ended ~~September 30, 2021~~March 31, 2022, the Company borrowed and ~~2020, respectively, included a tax benefit~~repaid $225.0 million under the Revolving Facility using net proceeds of ~~$1.1~~$222.0 million from at-the-market issuances of 10.1 million shares of common stock and ~~a tax provision~~available cash. The Company made no additional borrowings and terminated the facility on August 4, 2022.

Retirement of ~~$1.1 million, respectively,~~2022 Notes

On March 31, 2022, the Company retired the remaining principal balance of 2022 Notes upon maturity for $23.1 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 ~~remeasurement~~amortization of ~~foreign income tax accounts.~~ debt issuance costs.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Indebtedness	$	20.8	$	31.9	$	70.7	$	105.0
Financial assurance instruments	13.0		13.6		40.1		38.3
Interest expense	$	33.8	$	45.5	$	110.8	$	143.3

Cash paid for interest	$	26.4	$	40.0	$	104.2	$	144.3
Non-cash interest expense	$	4.6	$	4.9	$	13.6	$	15.2

The Senior Secured Term Loan is the Company’s ~~income tax benefit of $10.3 million and income tax provision of $2.7 million for the nine months ended~~only outstanding variable rate debt, which bore interest at LIBOR plus 2.75% per annum (5.83%) at September 30, ~~2021 and 2020, respectively, included a tax benefit of $1.6 million and a tax provision of $0.4 million, respectively, related~~2022. The rate increased to 6.33% on October 26, 2022.

Covenant Compliance

The Company was compliant with all relevant covenants under its debt agreements at September 30, 2022, including the ~~remeasurement of foreign income tax accounts.~~

~~As described in Note 11. “Long-term Debt,”~~minimum aggregate liquidity requirement under the Company ~~completed the Refinancing Transactions (as defined below),~~LC Agreement which included a senior notes exchange and related consent solicitation, a revolving credit facility exchange and various amendments to existing debt agreements. Generally, absent an exception, for U.S. tax purposes a debtor recognizes cancellation of debt income (CODI) upon discharge of its outstanding indebtedness for an amount of consideration less than the adjusted issue price of such indebtedness. The Company recognized CODI from the Refinancing Transactions of approximately $60 million, and the income will be offset byrequires the Company’s ~~operating losses.~~restricted subsidiaries to maintain minimum aggregate liquidity of $125.0 million at the end of each quarter through December 31, 2024.

~~(11) Long-term Debt~~ (10) Pension and Postretirement Benefit Costs

The ~~Company’s total funded indebtedness (Indebtedness) as~~components of ~~September 30, 2021~~net periodic pension and ~~December 31, 2020 consisted~~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 ~~the following:~~

Debt Instrument (defined below, as applicable) September 30, 2021 December 31, 2020
(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes) $ 23.1 $ 459.0
8.500% Senior Secured Notes due December 2024 (Peabody Notes) 128.8 —
10.000% Senior Secured Notes due December 2024 (Co-Issuer Notes) 193.9 —
6.375% Senior Secured Notes due March 2025 (2025 Notes) 462.4 500.0
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans) 206.0 —
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan) 328.7 388.2
Revolving credit facility — 216.0
Finance lease obligations 30.4 27.3
Less: Debt issuance costs (45.1) (42.7)
1,328.2 1,547.8
Less: Current portion of long-term debt 59.5 44.9
Long-term debt $ 1,268.7 $ 1,502.9
operations.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~Refinancing Transactions~~

On January 29, 2021 (the Settlement Date), the Company completed a series of transactions (collectively, the Refinancing Transactions) to, among other things, provide the Company with maturity extensions and covenant relief, while allowing it to maintain near-term operating liquidity and financial flexibility. The Refinancing Transactions included a senior notes exchange and related consent solicitation, a revolving credit facility exchange and various amendments to the Company’s existing debt agreements, as summarized below. As further discussed in Note 16. “Financial Instruments and Other Guarantees,” upon completion of the Refinancing Transactions, the surety transaction support agreement (Surety Agreement) entered into with the Company’s surety bond providers in November 2020 became effective.

On the Settlement Date, the Company settled an exchange offer (Exchange Offer) pursuant to which $398.7 million aggregate principal amount of the Company’s 6.000% Senior Secured Notes due March 2022 (the 2022 Notes) were validly tendered, accepted by the Company and exchanged for aggregate consideration consisting of (a) $193.9 million aggregate principal amount of new 10.000% Senior Secured Notes due December 2024 (Co-Issuer Notes) issued by certain wholly-owned subsidiaries of the Company (the Co-Issuers), (b) $195.1 million aggregate principal amount of new 8.500% Senior Secured Notes due December 2024 issued by the Company (Peabody Notes) and (c) a cash payment of approximately $9.4 million. In connection with the settlement of the Exchange Offer, the Company also paid early tender premiums totaling $4.0 million in cash. The Company’s Wilpinjong Mine in Australia is owned and operated by a subsidiary of the Co-Issuers.

The Exchange Offer was accounted for as a debt modification based upon the relative similarity of the present value of the future cash flows of the instruments. As such, 0 gain or loss was recorded in connection with the Exchange Offer. Fees paid to third parties of $10.6 million were included in “Interest expense” in the accompanying unaudited condensed consolidated statements of operations during the nine months ended September 30, 2021.

Concurrently with the Exchange Offer, the Company solicited consents from holders of the 2022 Notes to certain proposed amendments to its existing senior notes’ indenture (the Existing Indenture) to (i) eliminate substantially all of the restrictive covenants, certain events of default applicable to the 2022 Notes and certain other provisions contained in the Existing Indenture and (ii) release the collateral securing the 2022 Notes and eliminate certain other related provisions contained in the Existing Indenture. The Company received the requisite consents from holders of the 2022 Notes and entered into a supplemental indenture to the Existing Indenture, which became operative on January 29, 2021.

In connection with the Refinancing Transactions, the Company restructured the revolving loans under its existing credit agreement (the Credit Agreement) by (i) making a pay down of revolving loans thereunder in the aggregate amount of $10.0 million, (ii) the Co-Issuers incurring $206.0 million of term loans under a credit agreement, dated as of the Settlement Date (Co-Issuer Term Loans, Co-Issuer Term Loan Agreement), (iii) the Company entering into a letter of credit facility (the Company LC Agreement) and (iv) amending the Credit Agreement (collectively, the Revolver Transactions).

~~Co-Issuer Notes~~

The terms of the Co-Issuer Notes are governed by an indenture, as amended and restated as of February 3, 2021, by and among the Co-Issuers, Wilmington Trust, National Association, as trustee, and, on a limited basis, the Company (Co-Issuer Notes Indenture).

The Co-Issuer Notes mature on December 31, 2024 and bear interest at an annual rate of 10.000%. The Company paid aggregate debt issuance costs of $5.6 million, which are being amortized over the terms of the notes. Beginning March 31, 2021, interest is payable on March 31, June 30, September 30 and December 31 of each year. During the three and nine months ended September 30, 2021, the Company recorded interest expense of $5.4 million and $14.3 million, respectively, related to the Co-Issuer Notes.

The Co-Issuer Notes are subject to amortization at the end of each six-month period, beginning with June 30, 2021, whereby the Excess Cash Flow (as defined in the Co-Issuer Notes Indenture) generated by the Wilpinjong Mine during each such period will be applied to the principal of the Co-Issuer Notes and the Co-Issuer Term Loans on a pro rata basis, provided that the liquidity attributable to the Co-Issuers would not fall below $60.0 million.

The Co-Issuer Notes Indenture contains customary covenants that, among other things, limit the Co-Issuers’ and their subsidiaries’ ability to incur additional Indebtedness, pay dividends on or make distributions in respect of capital stock or make certain other restricted payments or investments, enter into agreements that restrict distributions from subsidiaries, sell or otherwise dispose of assets, enter into transactions with affiliates, create or incur liens, and merge, consolidate or sell all or substantially all of their assets, and place restrictions on the ability of subsidiaries to pay dividends or make other payments to the Co-Issuers.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

The Co-Issuer Notes are not guaranteed by any of the Co-Issuers’ subsidiaries and thus are structurally subordinated to any existing or future Indebtedness or other liabilities, including trade payables, of any such subsidiaries. The Co-Issuer Notes initially are secured by liens on substantially all of the assets of the Co-Issuers, including by (i) 100% of the capital stock of PIC Acquisition Corp. owned by PIC AU Holdings LLC and (ii) all other property subject or purported to be subject, from time to time, to a lien under the Co-Issuers’ collateral trust agreement (collectively, the Wilpinjong Collateral).

~~The Co-Issuers may redeem some or all of the Co-Issuer Notes at the redemption prices and on the terms specified in the Co-Issuer Notes Indenture.~~

The Co-Issuer Notes Indenture contains certain events of default, including, in certain circumstances, (i) specified events occurring at the Wilpinjong Mine, (ii) the termination or certain modifications of the Surety Agreement, (iii) the Company’s failure to comply with any obligation under the transaction support agreement entered into prior to, and in contemplation of, the Refinancing Transactions and (iv) the termination of the management services agreements between the Company and the Co-Issuers. If the Co-Issuer Notes are accelerated or otherwise become due and payable as a result of an event of default, certain additional premium amounts may become due and payable in addition to unpaid principal and interest at the time of acceleration. In addition, the holders of the Co-Issuer Notes have the right, under certain circumstances specified in the Co-Issuer Notes Indenture, to exchange their Co-Issuer Notes for Peabody Notes.

~~Peabody Notes~~

The terms of the Peabody Notes are governed by an indenture, as amended and restated as of February 3, 2021, by and among Peabody, the guarantors party thereto, and Wilmington Trust, National Association, as trustee (the Peabody Notes Indenture).

The Peabody Notes mature on December 31, 2024. The Company paid aggregate debt issuance costs of $5.7 million, which are being amortized over the terms of the notes. The Peabody Notes bear interest at an annual rate of 8.500%, consisting of 6.000% per annum in cash and an additional 2.500% per annum to be paid-in-kind through an increase of the principal amount of the outstanding Peabody Notes, which is payable on June 30 and December 31 of each year, commencing on June 30, 2021. During the three and nine months ended September 30, 2021, the Company recorded interest expense of $3.8 million and $10.8 million, respectively, related to the Peabody Notes, which included in-kind interest of approximately $0.8 million and $2.4 million, respectively.

As a requirement of the Exchange Offer, during the three months ended March 31, 2021, the Company purchased $22.4 million of the Peabody Notes at 80% of their accreted value, plus accrued and unpaid interest. In connection with the purchases, the Company recognized a net gain of $3.5 million to “Net gain on early debt extinguishment” during the nine months ended September 30, 2021. The notes were subsequently canceled.

The Peabody Notes Indenture contains customary covenants that, among other things, limit the Company’s and its restricted subsidiaries’ ability to incur additional Indebtedness, pay dividends on or make distributions in respect of capital stock or make certain other restricted payments or investments, enter into agreements that restrict distributions from restricted subsidiaries, sell or otherwise dispose of assets, enter into transactions with affiliates, create or incur liens, and merge, consolidate or sell all or substantially all of its assets, and place restrictions on the ability of subsidiaries to pay dividends or make other payments to the Company.

The Peabody Notes are unconditionally guaranteed, jointly and severally, on a senior secured basis by the Peabody Guarantors (as defined below) on the Peabody Collateral (as defined below). The obligations are secured on a ~~pari passu~~ ~~basis by the same collateral that secures the 6.375% Senior Secured Notes due March 2025 (the 2025 Notes), the Credit Agreement and the Company LC Agreement described below.~~

~~Co-Issuer Term Loans~~

The Co-Issuer Term Loans mature on December 31, 2024 and bear interest at a rate of 10.00% per annum. The Company paid aggregate debt issuance costs of $7.1 million, that are being amortized over its term. During the three and nine months ended September 30, 2021, the Company recorded interest expense of $5.7 million and $14.9 million, respectively, related to the Co-Issuer Term Loans.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

The Co-Issuer Term Loan Agreement contains customary covenants that, among other things, limit the Co-Issuers’ and their subsidiaries’ ability to incur additional Indebtedness, pay dividends on or make distributions in respect of capital stock or make certain other restricted payments or investments, enter into agreements that restrict distributions from subsidiaries, sell or otherwise dispose of assets, enter into transactions with affiliates, create or incur liens, and merge, consolidate or sell all or substantially all of their assets, and place restrictions on the ability of subsidiaries to pay dividends or make other payments to the Co-Issuers. The Co-Issuer Term Loan Agreement is guaranteed and secured to the same extent as the Co-Issuer Notes as described above. In addition, the Co-Issuer Term Loan Agreement contains events of default substantially similar to those described above for the Co-Issuer Notes Indenture.

~~Company LC Agreement~~

On the Settlement Date, the Company entered into the Company LC Agreement with the revolving lenders party to the Credit Agreement, pursuant to which the Company obtained a $324.0 million letter of credit facility under which its existing letters under the Credit Agreement were deemed to be issued. The Company paid aggregate debt issuance costs of $4.1 million. The commitments under the Company LC Agreement mature on December 31, 2024. Undrawn letters of credit under the Company LC Agreement bear interest at 6.00% per annum and unused commitments are subject to a 0.50% per annum commitment fee. During the three and nine months ended September 30, 2021, the Company recorded interest expense and fees of $6.0 million and $15.9 million, respectively, related to the Company LC Agreement.

In connection with the Revolver Transactions, the Company amended its Credit Agreement to make certain changes in consideration of the Company LC Agreement. After giving effect to the Revolver Transactions, there remain 0 revolving commitments or revolving loans under the Credit Agreement and the first lien net leverage ratio covenant was eliminated. The Company LC Agreement requires that the Company’s restricted subsidiaries maintain minimum aggregate liquidity of $125.0 million at the end of each quarter through December 31, 2024. As such, liquidity attributable to the Co-Issuers, its subsidiaries and other unrestricted subsidiaries is excluded from the calculation.

The Company LC Agreement is guaranteed and secured to the same extent of the Peabody Notes as described above. In addition, the Company LC Agreement contains events of default substantially similar to those described above for the Peabody Notes.

The Peabody Notes Indenture and the Company LC Agreement allow the Company to make open market debt repurchases, subject to certain limitations, including, but not limited to: (i) the Company’s unrestricted subsidiaries’ liquidity must be greater than or equal to $200.0 million after giving effect to such repurchases and (ii) for every $4 of principal repurchased in any fiscal quarter, the Company must make an offer on a pro rata basis to purchase $1 of principal amount of debt from holders of the Peabody Notes and the priority lien obligations under the Company LC Agreement within 30 days of the end of such fiscal quarter at a price equal to the weighted average repurchase price paid over that quarter (Mandatory Repurchase Offer).

~~6.375% Senior Secured Notes~~

On February 15, 2017, the Company entered into the Existing Indenture with Wilmington Trust, National Association, as trustee, relating to its issuance of $500.0 million aggregate principal amount of the 2025 Notes. The 2025 Notes were issued on February 15, 2017 in a private transaction exempt from the registration requirements of the Securities Act of 1933, as amended (the Securities Act).

The 2025 Notes were issued at par value. The Company paid aggregate debt issuance costs of $25.1 million related to the offering, which are being amortized over the term of the 2025 Notes. Interest payments on the 2025 Notes are scheduled to occur each year on March 31 and September 30 until maturity. The Company recorded interest expense of $9.5 million and $9.2 million during the three months ended September 30, 2021 and 2020, respectively, and $27.9 million and $27.5 million during the nine months ended September 30, 2021 and 2020, respectively, related to the 2025 Notes.

With respect to the 2025 Notes, the Existing Indenture contains customary conditions of default and imposes certain restrictions on the Company’s activities, including its ability to incur debt, incur liens, make investments, engage in fundamental changes such as mergers and dissolutions, dispose of assets, enter into transactions with affiliates and make certain restricted payments, such as cash dividends and share repurchases.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

The 2025 Notes rank senior in right of payment to any subordinated Indebtedness and equally in right of payment with any senior Indebtedness to the extent of the collateral securing that Indebtedness. The 2025 Notes are jointly and severally and fully and unconditionally guaranteed on a senior secured basis by substantially all of the Company’s domestic restricted subsidiaries (the Peabody Guarantors) and secured by (a) first priority liens over (1) substantially all of the assets of the Company and the Peabody Guarantors, except for certain excluded assets, (2) 100% of the capital stock of each domestic restricted subsidiary of the Company, (3) 100% of the capital stock of each first tier foreign subsidiary of the Company or a foreign subsidiary holding company and (4) all intercompany debt owed to the Company or any Peabody Guarantor, in each case, subject to certain exceptions (the Peabody Collateral), and (b) second priority liens over the Wilpinjong Collateral. The 2025 Notes are secured on a ~~pari passu~~ ~~basis by the same collateral securing the Credit Agreement, and the other priority lien debt of the Company, including the Peabody Notes and the Company LC Agreement described above.~~

~~Credit Agreement~~

The Company originally entered into the Credit Agreement during 2017, which provided for a $950.0 million senior secured term loan (the Senior Secured Term Loan) due in 2022. Proceeds from the Senior Secured Term Loan were received net of an original issue discount and deferred financing costs of $37.3 million that are being amortized over its term. The Credit Agreement has been amended periodically over its term to add a revolving loan facility, to increase the capacity and extend the maturity date of the revolving loan facility, to extend the maturity date of the Senior Secured Term Loan to 2025 and to make various changes to terms such as those related to interest, fees and payment restrictions. In connection with certain of the amendments, the Company voluntarily prepaid $46.0 million of Senior Secured Term Loan principal and incurred $10.4 million of deferred financing costs related to the revolving loan facility. The Company also voluntarily repaid an additional $500.0 million of Senior Secured Term Loan principal in various installments.

At September 30, 2021 the Senior Secured Term Loan had a balance of $328.7 million. The Senior Secured Term Loan requires quarterly principal payments of $1.0 million and periodic interest payments through December 2024 with the remaining balance due in March 2025. The Company recorded interest expense of $3.3 million and $3.4 million, during the three months ended September 30, 2021 and 2020, respectively, and $10.1 million and $12.1 million during the nine months ended September 30, 2021 and 2020, respectively, related to the Senior Secured Term Loan, which bore interest at LIBOR plus 2.75% per annum as of September 30, 2021.

In connection with the Revolver Transactions, the Company amended the Credit Agreement to make certain changes in consideration of the Company LC Agreement. After giving effect to the Revolver Transactions, there remain 0 revolving commitments or revolving loans under the Credit Agreement. Further, all financial covenants specific to the former revolving credit facility under the Credit Agreement were eliminated in connection with the Refinancing Transactions and were not applicable at September 30, 2021. The Company recorded interest expense and fees of $1.4 million during the nine months ended September 30, 2021, and $5.1 million and $10.8 million, during the three and nine months ended September 30, 2020, respectively, related to the revolving loan facility. NaN interest expense or fees related to the revolving loan facility were recorded during the three months ended September 30, 2021.

The Credit Agreement contains customary conditions of default and imposes certain restrictions on the Company’s activities, including its ability to incur liens, incur debt, make investments, engage in fundamental changes such as mergers and dissolutions, dispose of assets, enter into transactions with affiliates and make certain restricted payments, such as cash dividends and share repurchases. Obligations under the Credit Agreement are guaranteed by the Peabody Guarantors and are secured by first priority liens on the Peabody Collateral and second priority liens on the Wilpinjong Collateral. The obligations are secured on a ~~pari passu~~ ~~basis by the same collateral securing the 2025 Notes and the other priority lien debt of the Company, including the Peabody Notes and the Company LC Agreement described above.~~

~~The Company was compliant with all covenants under its debt agreements, including the minimum liquidity covenant under the Company LC Agreement, at September 30, 2021.~~

~~Subsequent Financing Transactions~~

~~Subsequent to the Refinancing Transactions, the Company completed a series of financing transactions intended to improve its capital structure.~~

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

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. During September 2021, the Company announced that it could offer and sell up to an additional 12.5 million shares, for a total of 25.0 million shares authorized through the at-the-market offering program. 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 and September 17, 2021, relating to the offer and sale of the shares. During the three and nine months ended September 30, 2021, the Company sold approximately 9.0 million shares and 17.1 million shares, respectively, for net cash proceeds of $112.1 million and $177.2 million, respectively. Between October 1, 2021 and November 2, 2021, the Company settled sales of an additional 3.2 million shares for net proceeds of $43.4 million.

During the three months ended September 30, 2021, the Company retired $22.1 million of Peabody Notes, $2.3 million of 2025 Notes and $38.9 million of its Senior Secured Term Loan primarily through various open market purchases at an aggregate cost of $46.7 million. The Company recorded a gain on early debt extinguishment of $15.0 million, net of debt issuance costs and original issue discount related to the retired debt of $1.6 million. During the nine months ended September 30, 2021, the Company retired $40.1 million of Peabody Notes, $19.7 million of 2025 Notes and $56.7 million of its Senior Secured Term Loan primarily through various open market purchases at an aggregate cost of $85.9 million. The Company recorded a gain on early debt extinguishment of $26.9 million, net of debt issuance costs and original issue discount related to the retired debt of $3.7 million.

Also during the three months ended September 30, 2021, the Company completed multiple bilateral transactions with holders of the 2022 Notes, the 2025 Notes and the Peabody Notes in which the Company issued an aggregate 2.2 million shares of its common stock in exchange for $6.4 million aggregate principal amount of the 2022 Notes, $17.9 million aggregate principal amount of the 2025 Notes and $5.5 million aggregate principal amount of the Peabody Notes. Based upon the fair value of the Company’s common stock at the respective settlement dates, the Company recorded a net gain on early debt extinguishment of $1.0 million in connection with the transactions. During the nine months ended September 30, 2021, the Company completed multiple bilateral transactions with holders of the 2022 Notes, the 2025 Notes and the Peabody Notes in which the Company issued an aggregate 6.7 million shares of its common stock in exchange for $37.3 million aggregate principal amount of the 2022 Notes, $17.9 million aggregate principal amount of the 2025 Notes and $5.5 million aggregate principal amount of the Peabody Notes. Based upon the fair value of the Company’s common stock at the respective settlement dates, the Company recorded a net gain on early debt extinguishment of $0.9 million in connection with the transactions. The issuance of shares of common stock in exchange for the 2022 Notes, the 2025 Notes and the Peabody Notes was made in reliance on the exemption from registration provided in Section 3(a)(9) under the Securities Act of 1933, based in part on representations of holders of the 2022 Notes, the 2025 Notes and the Peabody Notes, and on the basis that the exchange was completed with existing holders of the Company's securities and no commission or other remuneration was paid or given for soliciting the exchange.

Prior to September 30, 2021, the Company reached agreements to retire an additional $17.0 million of aggregate principal, which will settle subsequent to September 30, 2021. This included $5.0 million of its Senior Secured Term Loan through similar open market purchases for an aggregate cost of $3.3 million, and by issuing an aggregate 0.8 million shares of its common stock in exchange for $12.0 million aggregate principal amount of the Peabody Notes in a similar manner as noted above. Such amounts are reflected within the current portion of long-term debt in the accompanying condensed consolidated balance sheet at September 30, 2021.

Between October 1, 2021 and November 2, 2021, the Company reached additional agreements to issue an aggregate 1.1 million shares of its common stock in exchange for $19.0 million aggregate principal amount of the 2025 Notes, which was reflected within the long-term debt in the accompanying condensed consolidated balance sheet at September 30, 2021.

As a result of the Company’s open market purchases of its debt during the three months ended September 30, 2021, on October 22, 2021, the Company announced a Mandatory Repurchase Offer of up to $15.8 million of Peabody Notes, at 73.590% of their aggregate accreted value, plus accrued and unpaid interest, and a concurrent repurchase offer of priority lien obligations under the Company LC Agreement. The offers expire on November 22, 2021, unless extended by the Company.

~~Finance Lease Obligations~~

~~Refer to Note 9. “Leases” for additional information associated with the Company’s finance leases, which pertain to the financing of mining equipment used in operations.~~

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

~~(12) 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) costs, excluding service cost” in the unaudited condensed consolidated statements of operations.

Net periodic pension ~~benefit~~credit included the following components:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(Dollars in millions)									(Dollars in millions)
Service cost for benefits earned	Service cost for benefits earned	$	—	$	0.1	$	0.1	$	0.2	Service cost for benefits earned	$	0.1	$	—	$	0.1	$	0.1
Interest cost on projected benefit obligation	Interest cost on projected benefit obligation	5.2		7.0		15.4		21.0		Interest cost on projected benefit obligation	5.3		5.2		16.0		15.4
Expected return on plan assets	Expected return on plan assets	(5.8)		(7.5)		(17.2)		(22.3)		Expected return on plan assets	(6.0)		(5.8)		(17.9)		(17.2)

Net periodic pension benefit		$	(0.6)	$	(0.4)	$	(1.7)	$	(1.1)
Net periodic pension credit										Net periodic pension credit	$	(0.6)	$	(0.6)	$	(1.8)	$	(1.7)

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 September 30, ~~2021,~~2022, 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 ~~2021~~2022 based on minimum funding requirements and does not expect to make any discretionary contributions in ~~2021~~2022 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 Retirement Plan) with The Prudential Insurance Company of America (Prudential) and Fiduciary Counselors Inc., as independent fiduciary to the Peabody Retirement Plan. Under the commitment agreement, the Peabody Retirement Plan purchased a group annuity contract (GAC) from Prudential for approximately $500 million and Prudential will reimburse the Peabody Retirement Plan for benefit payments to be made to the Peabody Retirement Plan’s participants. The Peabody Retirement Plan continues to administer and pay the retirement benefits of Peabody Retirement Plan participants and is reimbursed by Prudential for the payment of all benefits covered by the GAC. The purchase of the GAC was funded directly by the Peabody Retirement Plan’s assets. There will be no impact on the monthly retirement benefits paid to Peabody Retirement Plan participants and no material impact on contributions for the Peabody Retirement Plan in 2022 as a result of this transaction.

In May 2022, the Board of Directors of PIC approved the termination of the Peabody Retirement Plan effective July 31, 2022. In June 2022, the Peabody Retirement Plan’s participants were notified of the Peabody Retirement Plan termination and the Peabody Retirement Plan 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 Retirement Plan. Once all regulatory approvals are received, benefits will be distributed to participants or transferred to an insurance company. Anticipated asset distribution, via voluntary lump sum payouts for active and deferred participants, is expected in the first half of 2023, following which participants not electing a lump sum and all participants in payment status will be transferred to a highly qualified insurance company.

Net periodic postretirement benefit ~~(benefit) cost~~credit included the following components:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(Dollars in millions)									(Dollars in millions)
Service cost for benefits earned	Service cost for benefits earned	$	0.3	$	1.1	$	0.8	$	3.3	Service cost for benefits earned	$	0.2	$	0.3	$	0.6	$	0.8
Interest cost on accumulated postretirement benefit obligation	Interest cost on accumulated postretirement benefit obligation	2.9		5.4		8.7		16.3		Interest cost on accumulated postretirement benefit obligation	1.7		2.9		5.2		8.7
Expected return on plan assets	Expected return on plan assets	(0.3)		(0.3)		(0.7)		(1.1)		Expected return on plan assets	(0.2)		(0.3)		(0.6)		(0.7)
Amortization of prior service credit	Amortization of prior service credit	(11.0)		(2.2)		(33.0)		(6.6)		Amortization of prior service credit	(13.4)		(11.0)		(40.3)		(33.0)
Net actuarial loss		—		13.0		—		13.0
Net periodic postretirement benefit (benefit) cost		$	(8.1)	$	17.0	$	(24.2)	$	24.9

Net periodic postretirement benefit credit										Net periodic postretirement benefit credit	$	(11.7)	$	(8.1)	$	(35.1)	$	(24.2)

In ~~September 2020,~~October 2021, the Company announced changes to its postretirement health care benefit ~~plans~~plan for ~~non-represented employees and~~certain represented retirees which reduced its accumulated postretirement benefit obligation, as further described in Note ~~15.~~14. “Postretirement Health Care and Life Insurance Benefits” in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021. The reduction in liability was recorded with an offsetting balance in “Accumulated other comprehensive income” and is being amortized to earnings.

The Company has established two Voluntary Employees Beneficiary Association (VEBA) trusts to pre-fund a portion of benefits for non-represented and represented retirees. The Company does not expect to make any discretionary contributions to either of the VEBA trusts in 2021 and plans to utilize a portion of VEBA assets to make certain benefit payments.

In October 2021, the Company announced changes to its postretirement health care benefit plan for certain represented retirees. Effective January 1, 2022, the Company will not provide medical coverage to certain existing retirees but will continue to offer a life insurance benefit to eligible retirees. As of September 30, 2021, the health care benefit obligation attributed to these certain existing retirees is approximately $160 million. The impact of the changes will reduce the Company’s postretirement benefit obligation during the fourth quarter of 2021. The liability is expected to be remeasured, with the resulting benefit of the plan changes recorded in “Accumulated other comprehensive income” and amortized to future earnings based upon the estimated remaining life expectancies of certain plan participants.

2520

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~(13) Accumulated Other Comprehensive Income~~

The ~~following table sets forth~~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 ~~after-tax components~~VEBA trust in 2022 and plans to utilize a portion of ~~accumulated other comprehensive income and changes thereto recorded during the nine months ended September 30, 2021:~~

Foreign Currency Translation
Adjustment Prior Service
Credit Associated
with
Postretirement
Plans Total Accumulated Other Comprehensive Income
(Dollars in millions)
December 31, 2020 $ 1.8 $ 204.0 $ 205.8
Reclassification from other comprehensive income to earnings — (33.0) (33.0)
Current period change (1.2) — (1.2)
September 30, 2021 $ 0.6 $ 171.0 $ 171.6

~~Postretirement health care and life insurance benefits reclassified from other comprehensive income~~VEBA assets to ~~earnings of $11.0 million and $2.2 million during the three months ended September 30, 2021 and 2020, respectively, and $33.0 million~~ ~~and $6.6 million during the nine months ended September 30, 2021 and 2020, respectively, are included in “Net periodic~~make certain benefit ~~(credit) costs, excluding service cost” in the unaudited condensed consolidated statements of operations.~~payments.

~~(14) Other Events~~

From time to time, the Company initiates restructuring activities in connection with its repositioning efforts to appropriately align its cost structure or optimize its coal production relative to prevailing market conditions. Costs associated with restructuring actions can include the impact of early mine closures, voluntary and involuntary workforce reductions, office closures and other related activities. Costs associated with restructuring activities are recognized in the period incurred. Such charges included as “Restructuring charges” in the Company's unaudited condensed consolidated statements of operations amounted to $1.7 million and $5.9 million for the three and nine months ended September 30, 2021, respectively, and $8.1 million and $31.1 million for the three and nine months ended September 30, 2020, respectively, were associated with both involuntary and voluntary workforce reductions.

In September 2021, the Company reached a new collective bargaining agreement with the UMWA on behalf of the hourly workforce of its Shoal Creek Mine. The Company idled the mine in the fourth quarter of 2020 due to market conditions. During the idle period the Company undertook activities, including a preparation plant upgrade project, to increase productivity, lower costs and improve yields from the operation in the future. The Company expects to begin production at Shoal Creek Mine in the second half of the fourth quarter of 2021, with ramp up through the first quarter of 2022.

The full workforce of the Metropolitan Mine, which was idled in December 2020, returned to the mine in May 2021. Development work at the mine has been ongoing and longwall production restarted late in the second quarter of 2021, with a ramp up to planned production levels in the fourth quarter of 2021. The underground workforce enterprise agreement expired in January 2021 and was renegotiated in October 2021.

During July 2021, the Company executed transactions to sell its closed Millennium and Wilkie Creek Mines, which reduced its closed mine reclamation liabilities and associated costs. The Millennium Mine was sold for minimal cash consideration and the assumption of the majority of the mine’s reclamation liabilities. The Company will remain responsible for $9.4 million of reclamation liabilities and retains certain royalty rights on future sales. The Company recorded a gain of $26.1 million in connection with the sale, and will recognize royalty revenue when it is deemed collectible. The gain is included within “Net gain on disposals” in the accompanying unaudited condensed consolidated statements of operations.

The Wilkie Creek Mine was sold for minimal cash consideration and full assumption of the mine’s reclamation liabilities. The Company retains certain royalty rights on future sales. The Company recorded a gain of $24.6 million in connection with the sale, and will recognize royalty revenue when it is deemed collectible. The gain is included within “Income (loss) from discontinued operations, net of income taxes” in the accompanying unaudited condensed consolidated statements of operations.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

~~(15)~~(11) Earnings per Share (EPS)

Basic EPS is computed based on the weighted average number of shares of common stock outstanding during the period. Diluted EPS is computed based on the weighted average number of shares of common stock plus the effect of dilutive potential common shares outstanding. As such, the Company includes the 2028 Convertible Notes and share-based compensation awards in its potentially dilutive securities. ~~Dilutive~~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 related to the convertible debt.

The computation of diluted EPS excluded aggregate share-based compensation awards of less than 0.1 million for both the three and nine months ended September 30, 2022, and approximately 0.9 million and ~~2.1~~0.8 million for the three ~~months ended September 30, 2021~~ and ~~2020, respectively, and 0.8 million and 2.3 million for the~~ nine months ended September 30, 2021, ~~and 2020,~~ respectively, because to do so would have been anti-dilutive for those periods. Because the potential dilutive impact of such share-based compensation awards is calculated under the treasury stock method, anti-dilution generally occurs when the exercise prices or unrecognized compensation cost per share of such awards are higher than the Company’s average stock price during the applicable period. Anti-dilution also occurs when a company reports a net loss from continuing operations, and the dilutive impact of all share-based compensation awards are excluded accordingly.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(In millions, except per share data)
EPS numerator:
Loss from continuing operations, net of income taxes $ (59.6) $ (64.8) $ (160.3) $ (1,739.4)
Less: Net income (loss) attributable to noncontrolling interests 8.9 0.1 12.6 (5.1)
Loss from continuing operations attributable to common stockholders (68.5) (64.9) (172.9) (1,734.3)
Income (loss) from discontinued operations, net of income taxes 24.3 (2.3) 20.0 (6.8)
Net loss attributable to common stockholders $ (44.2) $ (67.2) $ (152.9) $ (1,741.1)
EPS denominator:
Weighted average shares outstanding — basic and diluted 114.9 97.9 104.9 97.6
Basic and diluted EPS attributable to common stockholders:
Loss from continuing operations $ (0.60) $ (0.66) $ (1.65) $ (17.76)
Income (loss) from discontinued operations 0.22 (0.03) 0.19 (0.07)
Net loss attributable to common stockholders $ (0.38) $ (0.69) $ (1.46) $ (17.83)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(In millions, except per share data)
Basic EPS numerator:
Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	675.9	$	(160.3)
Less: Net income attributable to noncontrolling interests	8.5		8.9		8.5		12.6
Income (loss) from continuing operations attributable to common stockholders	375.9		(68.5)		667.4		(172.9)


(Loss) income from discontinued operations, net of income taxes	(0.8)		24.3		(2.3)		20.0


Net income (loss) attributable to common stockholders	$	375.1	$	(44.2)	$	665.1	$	(152.9)

Diluted EPS numerator:
Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	675.9	$	(160.3)
Add: Tax adjusted interest expense related to 2028 Convertible Notes	2.6		—		6.1		—
Less: Net income attributable to noncontrolling interests	8.5		8.9		8.5		12.6
Income (loss) from continuing operations attributable to common stockholders	378.5		(68.5)		673.5		(172.9)
(Loss) income from discontinued operations, net of income taxes	(0.8)		24.3		(2.3)		20.0
Net income (loss) attributable to common stockholders	$	377.7	$	(44.2)	$	671.2	$	(152.9)

EPS denominator:
Weighted average shares outstanding — basic	144.1		114.9		141.4		104.9
Dilutive impact of share-based compensation awards	1.7		—		1.6		—
Dilutive impact of 2028 Convertible Notes	16.1		—		12.6		—
Weighted average shares outstanding — diluted	161.9		114.9		155.6		104.9

Basic EPS attributable to common stockholders:
Income (loss) from continuing operations	$	2.61	$	(0.60)	$	4.72	$	(1.65)
(Loss) income from discontinued operations	(0.01)		0.22		(0.02)		0.19
Net income (loss) attributable to common stockholders	$	2.60	$	(0.38)	$	4.70	$	(1.46)

Diluted EPS attributable to common stockholders:
Income (loss) from continuing operations	$	2.34	$	(0.60)	$	4.33	$	(1.65)
(Loss) income from discontinued operations	(0.01)		0.22		(0.02)		0.19
Net income (loss) attributable to common stockholders	$	2.33	$	(0.38)	$	4.31	$	(1.46)

~~(16)~~(12) Financial Instruments and Other Guarantees

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. At September 30, ~~2021,~~2022, such instruments included ~~$1,462.4~~$1,380.5 million of surety bonds and ~~$443.2~~$505.4 million of letters of credit. Such financial instruments provide support for the Company’s reclamation bonding requirements, lease obligations, insurance policies and various other performance guarantees. Reclamation bonding requirements are typically established by statute or under mining permits. At September 30, 2021, the Company’s asset retirement obligations of $710.2 million were supported by surety bonds of $1,293.4 million, as well as letters of credit issued under the Company’s receivables securitization program and the Company LC Agreement. Letters of credit issued at September 30, 2021 which served as collateral for surety bonds in support of asset retirement obligations amounted to $316.1 million.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

In November 2020, the Company entered into a Surety Agreement with the providers of 99% of its surety bond portfolio (Participating Sureties) to resolve previous collateral demands made by the Participating Sureties. In accordance with the Surety Agreement, the Company initially provided $75.0 million of collateral, in the form of letters of credit.

Upon completion of the Refinancing Transactions described in Note 11. “Long-term Debt,” other provisions of the Surety Agreement became effective. In particular, the Company granted second liens on $200.0 million of certain mining equipment and will post an additional $25.0 million of collateral per year from 2021 through 2024 for the benefit of the Participating Sureties. The collateral postings may also further increase to the extent the Company generates more than $100.0 million of free cash flow (as defined in the Surety Agreement) in any twelve-month period or has cumulative asset sales in excess of $10.0 million, as of the last quarter end during the term of the agreement. Further, the Participating Sureties have agreed to a standstill through the earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025), during which time, the Participating Sureties will not demand any additional collateral, draw on letters of credit posted for the benefit of themselves or cancel any existing surety bond. The Company will not pay dividends or make share repurchases during the standstill period, unless otherwise agreed between parties. In connection with the Refinancing Transactions, at the Settlement Date, all letters of credit issued under the Company’s former revolving credit facility were deemed issued under the Company LC Agreement in support of the same obligations.

The Company periodically evaluates the instruments for on-balance sheet treatment based on the amount of exposure under the instrument and the likelihood of required performance. The Company does not expect any material losses to result from these guarantees or off-balance-sheet instruments in excess of liabilities provided for in the accompanying condensed consolidated balance sheets.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Reclamation Bonding

The Company is required to provide various forms of financial assurance in support of its mining reclamation obligations in the jurisdictions in which it operates. Such requirements are typically established by statute or under mining permits.

In November 2020, the Company entered into an agreement with the providers of its surety bond portfolio to resolve previous collateral demands. In accordance with the agreement, the Company initially provided $75.0 million of collateral, in the form of letters of credit. The Company subsequently granted second liens on $200.0 million of certain mining equipment and is further required to post an additional $25.0 million of collateral per year from 2021 through 2024 for the benefit of the surety providers. The collateral postings further increase to the extent the Company generates more than $100.0 million of free cash flow (as defined in the surety agreement) in any twelve-month period or has cumulative asset sales in excess of $10.0 million, as of the last quarter end during the term of the agreement. Based upon the Company’s free cash flow since entering into the surety agreement, additional collateral of $38.7 million was posted during the nine months ended September 30, 2022 and $57.4 million was posted subsequent to September 30, 2022, primarily in the form of cash-collateralized letters of credit.

At September 30, 2022, the Company’s asset retirement obligations of $725.8 million were supported by surety bonds of $1,234.6 million, as well as letters of credit issued under the Company’s receivables securitization program and the Company LC Agreement. Letters of credit issued at September 30, 2022 which served as collateral for surety bonds in support of asset retirement obligations amounted to $369.9 million.

Accounts Receivable Securitization

The Company ~~is party~~entered into the Sixth Amended and Restated Receivables Purchase Agreement, as amended, dated as of April 3, 2017 (the Receivables Purchase Agreement) to ~~an accounts receivable~~extend the Company’s receivables securitization ~~agreement~~facility previously in place and expand that facility to include certain receivables from the Company’s Australian operations. The receivables securitization program (Securitization Program) ~~which expires~~is subject to customary events of default set forth in ~~April~~the Receivables Purchase Agreement. The Receivables Purchase Agreement was amended in January 2022 ~~and provides up~~ to extend the Securitization Program to January 2025, reduce the available funding capacity from $250.0 million into $175.0 million, and amend the relevant borrowing rate from a LIBOR-based rate to one based on Bloomberg’s Short-Term Bank Yield Index (BSBY). 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, from time to time. Funding capacity under the Securitization Program may also be utilized for letters of credit in support of other obligations. ~~The borrowings~~

Borrowings under the Securitization Program bear interest at ~~LIBOR~~BSBY plus ~~1.5%~~2.1% per annum and remain outstanding throughout the term of the agreement, subject to the Company maintaining sufficient eligible ~~receivables, by continuing to contribute trade receivables, unless an event of default occurs. The Securitization Program is subject to customary events of default.~~

Under the terms of the Securitization Program, the Company contributes the trade receivables of its participating subsidiaries on a revolving basis to a wholly-owned, bankruptcy-remote subsidiary, which then sells the receivables to unaffiliated banks. The Securitization Program does not receive off-balance sheet accounting treatment due to the Company’s ability to repurchase the receivables in certain circumstances.receivables.

At September 30, ~~2021,~~2022, the Company had no outstanding borrowings and ~~$133.6~~$164.1 million of letters of credit ~~issued~~outstanding under the Securitization Program. The letters of credit were primarily in support of reclamation obligations. Availability under the Securitization Program, which is adjusted for certain ineligible receivables, was ~~$12.6~~$10.9 million at September 30, ~~2021.~~2022. The Company was not required to post cash collateral under the Securitization Program at ~~either~~ September 30, ~~2021 or December 31, 2020.~~2022.

The Company incurred interest and fees associated with the Securitization Program of ~~$1.0~~$1.2 million and ~~$0.8~~$1.0 million during the three months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively, and ~~$3.0~~$3.4 million and ~~$2.9~~$3.0 million during the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively, which have been recorded as “Interest expense” in the accompanying unaudited condensed consolidated statements of operations.

~~Other~~Collateralized Letter of Credit Agreement

~~Substantially all~~In February 2022, the Company entered into a new agreement, which provides up to $250.0 million of capacity for irrevocable standby letters of credit, expected to primarily support reclamation bonding requirements. The agreement requires the Company to provide cash collateral at a level of 103% of the ~~Company’s U.S. subsidiaries provide financial guarantees under long-term debt agreements entered into by the Company. The maximum amounts payable~~aggregate amount of letters of credit outstanding under the ~~Company’s debt agreements are equal~~arrangement (limited to $5.0 million total excess collateralization.) Outstanding letters of credit bear a fixed fee in the ~~respective principal~~amount of 0.75% per annum. The Company receives a deposit rate of 2.24% per annum on the amount of cash collateral posted in support of letters of credit, with the rate subject to variation over time. The agreement has an initial expiration date of December 31, 2025. At September 30, 2022, collateralized letters of credit of $43.2 million were outstanding under the agreement. The underlying collateral balance of $44.5 million at September 30, 2022 is included with “Investments and ~~interest payments.~~other assets” in the accompanying condensed consolidated balance sheets.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~(17)~~Other

As of September 30, 2022, the Company had other collateral balances of $60.9 million posted, including $43.8 million related to reclamation, which are included with “Investments and other assets” in the accompanying condensed consolidated balance sheets. Such collateral balances amounted to $23.8 million at December 31, 2021, including $15.0 million related to reclamation.

(13) Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of September 30, ~~2021,~~2022, purchase commitments for capital expenditures were ~~$23.4~~$77.8 million, all of which is obligated within the next ~~four~~three years, with ~~$16.2~~$71.3 million obligated within the next 12 months.

There were no other material changes to the Company’s commitments from the information provided in Note ~~24.~~23. “Commitments and Contingencies” to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021.

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 results of operations for the periods presented.

Litigation and Matters Relating to Continuing Operations

Securities Class Action. On September 28, 2020, the Oklahoma Firefighters Pension and Retirement System brought a lawsuit, styled In Re Peabody Energy Corporation Securities Litigation No. 1:20-cv-08024 (PKC), against the Company and certain of its officers in the U.S. District Court for the Southern District of New York (the Court) on behalf of a putative class of shareholders (Plaintiffs) who held Company stock between April 3, 2017 and October 28, 2019, for alleged violations of Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 and Rule 10b-5 promulgated thereunder (Securities Class Action). Plaintiffs ~~allege~~alleged that the defendants made false or misleading statements and/or failed to disclose certain adverse facts pertaining to safety practices at the Company’s North Goonyella Mine and the events leading up to a fire at the mine, and that, after a September 28, 2018 fire at the mine, made false or misleading statements and/or failed to disclose certain adverse facts pertaining to the feasibility of the Company’s plan to restart the mine after the fire. ~~The Company believes the lawsuit lacks merit and intends to vigorously defend against the allegations.~~ On January 12, 2021, the Court appointed the Oregon Public Employees Retirement Fund as lead plaintiff. On January 25, 2021, the Court entered a scheduling order for this matter. Plaintiffs filed their amended complaint on March 19, 2021. The defendants filed a pre-motion letter on April 30, 2021, while the Plaintiffs’ response letter was filed on May 6, 2021. The defendants filed their motion to dismiss on June 7, 2021. The Plaintiffs’ opposition brief to the motion to dismiss was filed on July 22, 2021. The defendants filed their reply to ~~Plaintiff’s~~Plaintiffs’ opposition on August 23, 2021, ~~completing briefing at~~which completed briefing. On March 7, 2022, the Court granted in part and denied in part the defendants’ motion to dismiss. As a result of this ~~phase~~decision, only Plaintiffs’ allegations relating to the Company’s September 25, 2018 statements remained in the case. On May 13, 2022, the Court entered a Case Management and Scheduling Order.

On August 2, 2022, Peabody and Plaintiffs agreed to settle all claims brought on behalf of all persons who purchased or otherwise acquired the Company’s shares between April 3, 2017 and October 28, 2019 in exchange for $4.6 million, to be paid by Peabody’s insurers. The parties further agreed to negotiate in good faith and execute a definitive stipulation of settlement and related documents, which are subject to the Court’s approval. The stipulation of settlement will not contain any admission of liability, wrongdoing or responsibility by any of the ~~litigation.~~parties and will provide that upon final approval of the settlement, the case will be dismissed with prejudice, with mutual releases by all parties.

On October 13, 2022, the Court entered an Order of Preliminary Approval of the settlement agreement. A hearing date of February 7, 2023 is set for final approval of the settlement agreement.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Derivative Actions. On December 22, 2020, a plaintiff (Phelps), putatively on behalf of the Company, brought a shareholder derivative lawsuit, styled Phelps v. Samantha Algaze, et al., Case No. 1:20-cv-01747-UNA (D. Del. filed Dec. 22, 2020), in the U.S. District Court for the District of Delaware against certain directors and former officers of the Company, as defendants. The Company was also named as a nominal defendant. The plaintiff did not make a demand on the Company’s board before instituting the lawsuit and alleges such demand would have been futile. In the complaint, the plaintiff alleges that the defendants failed to disclose adverse facts relating to the safety practices at the Company’s North Goonyella Mine, thereby leading to a September 28, 2018 fire, and allegedly failed to disclose adverse facts pertaining to the feasibility of reopening the mine. The derivative complaint alleges (i) contribution against certain current and former officers for securities fraud based on the Securities Class Action, and against all defendants, (ii) breach of fiduciary duties, (iii) waste of corporate assets for causing the Company to incur legal liability and (iv) unjust enrichment.

On February 10, 2021, a second plaintiff (Di Fusco), putatively on behalf of the Company, filed a similar shareholder derivative lawsuit, styled Di Fusco v. Glenn Kellow, et al., Case No. 1:21-cv-00183-UNA (D. Del. filed Feb. 10, 2021), in the U.S. District Court for the District of Delaware against the directors and current and former officers of the Company, as defendants. The Company was named as a nominal defendant. This suit makes claims similar to those made in the Phelps matter, but asserts a claim for alleged misstatements in a proxy statement under Section 14(a) of the Securities and Exchange Act of 1934. In late March 2021, the parties filed a stipulation agreeing to consolidate and stay both derivative actions for judicial efficiency and cost until the Court ~~rules~~ruled on the motion to dismiss in the Securities Class Action.

In light of the settlement agreement in the Securities Class Action, on September 7, 2022, the Court entered Stipulation and Order of Voluntary Dismissal Without Prejudice Pursuant to Fed. R. Civ. P. 419a)(1)(A)(ii) for the Phelps and Di Fusco matters; effectively closing the shareholder derivative lawsuits.

Metropolitan Mine Stormwater Discharge. Over the past two 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. During this period of time, Metropolitan Collieries Pty Ltd (MCPL), a wholly-owned subsidiary of PEC, has been actively undertaking works, including the use of long reach excavators and pumping systems, to remove accumulated material from the sedimentation dams to restore full site stormwater capacity. 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. The ~~Company also believes that the derivative actions lack merit and intends to vigorously defend~~Environment Protection Authority is investigating potential offenses against the ~~allegations.~~

~~Table~~environmental protection legislation. MCPL is fully cooperating with the Environment Protection Authority in relation to this investigation and has also engaged external consultants to undertake a review of ~~Contents~~the surface water management infrastructure. MCPL is in ongoing discussions with the Environmental Protection Authority with respect to the timeline for the restoration of stormwater capacity and sediment removal.

~~PEABODY ENERGY CORPORATION~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)~~

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 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

~~(18)~~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 in the U.S. District Court for the Eastern District of Virginia 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.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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. 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 $85.7 million and $87.2 million at September 30, 2022 and December 31, 2021, respectively. The liability, which is classified as discontinued operations, is included in the Company’s condensed consolidated balance sheet 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.

(14) Segment Information

The Company reports its results of operations primarily through the following reportable segments: Seaborne Thermal Mining, Seaborne Metallurgical Mining, Powder River Basin Mining, Other U.S. Thermal Mining 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.~~performance and allocate resources.

Adjusted EBITDA is a non-GAAP financial measure defined as ~~loss~~income (loss) 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 non-GAAP performance measures are used by investors to measure the Company’s operating performance and lenders to measure the Company’s ability to incur and service debt. 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 September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Revenues:
Seaborne Thermal Mining $ 260.7 $ 163.0 $ 631.2 $ 526.1
Seaborne Metallurgical Mining 179.5 78.8 388.0 363.6
Powder River Basin Mining 247.1 264.8 724.1 737.2
Other U.S. Thermal Mining 184.6 179.8 496.0 524.1
Corporate and Other (192.9) (15.4) (185.6) (7.1)
Total $ 679.0 $ 671.0 $ 2,053.7 $ 2,143.9
Adjusted EBITDA:
Seaborne Thermal Mining $ 104.4 $ 35.3 $ 204.3 $ 118.1
Seaborne Metallurgical Mining 57.4 (27.3) 8.6 (96.1)
Powder River Basin Mining 37.0 78.3 112.6 143.0
Other U.S. Thermal Mining 45.1 51.6 125.6 123.0
Corporate and Other 45.2 (42.5) 21.2 (132.4)
Total $ 289.1 $ 95.4 $ 472.3 $ 155.6

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Reportable segment results were as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Revenue:
Seaborne Thermal Mining	$	353.2	$	260.7	$	959.3	$	631.2
Seaborne Metallurgical Mining	310.7		179.5		1,165.8		388.0
Powder River Basin Mining	290.5		247.1		771.4		724.1
Other U.S. Thermal Mining	261.4		184.6		689.4		496.0
Corporate and Other	126.7		(192.9)		(230.1)		(185.6)
Total	$	1,342.5	$	679.0	$	3,355.8	$	2,053.7

Adjusted EBITDA:
Seaborne Thermal Mining	$	171.2	$	104.4	$	438.5	$	204.3
Seaborne Metallurgical Mining	113.2		57.4		593.9		8.6
Powder River Basin Mining	37.9		37.0		43.5		112.6
Other U.S. Thermal Mining	72.7		45.1		184.6		125.6
Corporate and Other	43.9		45.2		83.7		21.2
Total	$	438.9	$	289.1	$	1,344.2	$	472.3

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


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(Dollars in millions)									(Dollars in millions)
Loss from continuing operations, net of income taxes		$	(59.6)	$	(64.8)	$	(160.3)	$	(1,739.4)
Income (loss) from continuing operations, net of income taxes										Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	675.9	$	(160.3)
Depreciation, depletion and amortization	Depreciation, depletion and amortization	77.9		72.2		223.3		266.5		Depreciation, depletion and amortization	80.7		77.9		227.4		223.3
Asset retirement obligation expenses	Asset retirement obligation expenses	14.3		14.3		45.3		46.0		Asset retirement obligation expenses	13.1		14.3		40.8		45.3
Restructuring charges	Restructuring charges	1.7		8.1		5.9		31.1		Restructuring charges	1.0		1.7		2.8		5.9
Transaction costs related to joint ventures		—		6.0		—		23.1

Asset impairment	Asset impairment	—		—		—		1,418.1		Asset impairment	1.7		—		1.7		—

Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	(6.4)		(0.5)		(8.4)		(1.6)		Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	(0.5)		(6.4)		(1.7)		(8.4)
Interest expense	Interest expense	45.5		34.9		143.3		102.3		Interest expense	33.8		45.5		110.8		143.3
Net gain on early debt extinguishment		(16.0)		—		(31.3)		—
Net loss (gain) on early debt extinguishment										Net loss (gain) on early debt extinguishment	8.7		(16.0)		34.5		(31.3)
Interest income	Interest income	(1.4)		(1.6)		(4.2)		(7.1)		Interest income	(4.9)		(1.4)		(6.3)		(4.2)
Net mark-to-market adjustment on actuarially determined liabilities		—		13.0		—		13.0
Unrealized losses on derivative contracts related to forecasted sales		238.4		16.1		264.0		11.3
Unrealized (gains) losses on foreign currency option contracts		(0.6)		(0.7)		8.2		(3.6)

Unrealized (gains) losses on derivative contracts related to forecasted sales										Unrealized (gains) losses on derivative contracts related to forecasted sales	(90.4)		238.4		235.1		264.0
Unrealized losses (gains) on foreign currency option contracts										Unrealized losses (gains) on foreign currency option contracts	1.4		(0.6)		4.4		8.2

Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition	(1.0)		(1.5)		(3.2)		(6.8)		Take-or-pay contract-based intangible recognition	(0.8)		(1.0)		(2.2)		(3.2)
Income tax (benefit) provision		(3.7)		(0.1)		(10.3)		2.7
Income tax provision (benefit)										Income tax provision (benefit)	10.7		(3.7)		21.0		(10.3)
Adjusted EBITDA	Adjusted EBITDA	$	289.1	$	95.4	$	472.3	$	155.6	Adjusted EBITDA	$	438.9	$	289.1	$	1,344.2	$	472.3

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(15) Other Events

During July 2021, the Company executed transactions to sell its closed Millennium and Wilkie Creek Mines, which reduced its closed mine reclamation liabilities and associated costs. The Millennium Mine was sold for minimal cash consideration and the assumption of the majority of the mine’s reclamation liabilities. At September 30, 2022, the Company remains responsible for $6.4 million of reclamation liabilities. The Company recorded a gain of $26.1 million in connection with the sale, which is included within “Net gain on disposals” in the accompanying unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2021.

The Wilkie Creek Mine was sold for minimal cash consideration and full assumption of the mine’s reclamation liabilities. The Company recorded a gain of $24.6 million in connection with the sale, which is included within “(Loss) income from discontinued operations, net of income taxes” in the accompanying unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2021.

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

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

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

Cautionary Notice Regarding Forward-Looking Statements

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

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

When considering these forward-looking statements, you should keep in mind the cautionary statements in this document and in the Company’s other Securities and Exchange Commission (SEC) filings, including, but not limited to, the more detailed discussion of these factors and other factors that could affect its results contained in Item 1A. “Risk Factors” and Item 3. “Legal Proceedings” of its Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 filed with the SEC on February ~~23, 2021.~~18, 2022. 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 ~~is a~~are financial ~~measure~~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 ~~Revenues~~Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton for each mining segment. These metrics are used by management to measure each of its mining segments’ operating performance. Management believes Costs per Ton and Adjusted EBITDA Margin per Ton best reflect controllable costs and operating results at the mining 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 Free Cash Flow which is also a non-GAAP measure. Free Cash Flow is used by management as a measure of its financial performance and 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 and lenders to measure its ability to incur and service debt. These measures are not intended to serve as alternatives to U.S. GAAP measures of performance and may not be comparable to similarly-titled measures presented by other companies. Refer to the “Reconciliation of Non-GAAP Financial Measures” section contained within this Item 2 for definitions and reconciliations to the most comparable measures under U.S. GAAP.

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Overview

Peabody is a leading ~~coal producer.~~producer of metallurgical and thermal coal. In ~~2020,~~2021, the Company produced and sold ~~128.8~~126.9 million and ~~132.6~~130.1 million tons of coal, respectively, from continuing operations. At September 30, ~~2021,~~2022, 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, both as principal and agent, and trades coal and freight-related contracts.

The Company reports its results of operations primarily through the following reportable segments: Seaborne Thermal Mining, Seaborne Metallurgical Mining, Powder River Basin Mining, Other U.S. Thermal Mining and Corporate and Other. Refer to Note ~~18.~~14. “Segment Information” to the accompanying unaudited condensed consolidated financial statements for further information regarding those segments and the components of its Corporate and Other segment.

Spot pricing for premium low-vol hard coking coal (Premium HCC), premium low-vol pulverized coal injection (Premium PCI) coal, Newcastle index thermal coal and API 5 index thermal coal, and prompt month pricing for PRB 8,880 Btu/Lb coal and Illinois Basin 11,500 Btu/Lb coal during the three months ended September 30, ~~2021~~2022 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 September 30, ~~2021~~2022 due to quality differentials and ~~the majority~~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.~~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 bi-annual, 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 September 30, ~~2021~~2022 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		September 30, 2021			High		Low		Average		September 30, 2022		October 31, 2022
Premium HCC (1)	Premium HCC (1)	$	408.50	$	198.00	$	263.66	$	388.50	Premium HCC (1)	$	302.00	$	188.00	$	249.75	$	270.50	$	311.50
Premium PCI coal (1)	Premium PCI coal (1)	255.50		145.25		185.37		242.50		Premium PCI coal (1)	280.50		180.50		244.78		269.25		306.00
Newcastle index thermal coal (1)	Newcastle index thermal coal (1)	203.20		140.08		166.17		203.20		Newcastle index thermal coal (1)	452.81		390.36		420.99		414.80		373.21
API 5 thermal coal (1)		111.00		76.09		93.17		111.00
API 5 index thermal coal (1)										API 5 index thermal coal (1)	214.12		167.83		195.50		167.83		150.00
PRB 8,800 Btu/Lb coal (2)	PRB 8,800 Btu/Lb coal (2)	24.00		12.50		14.49		24.00		PRB 8,800 Btu/Lb coal (2)	18.70		16.55		17.38		17.10		17.10
Illinois Basin 11,500 Btu/Lb coal (2)	Illinois Basin 11,500 Btu/Lb coal (2)	66.00		41.00		53.28		66.00		Illinois Basin 11,500 Btu/Lb coal (2)	196.00		170.00		187.45		195.00		178.00

(1) Prices expressed per metric tonne.

(2) Prices expressed per short ton.

Within the global coal industry, supply and demand ~~disruptions were widespread as~~for its products and the supplies used for mining have been impacted by the ongoing Russian-Ukrainian conflict and the coronavirus (COVID-19) pandemic. 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, the COVID-19 pandemic ~~forced country-wide lockdowns~~ and ~~regional restrictions. Future COVID-19-related developments~~rising inflation are unknown, ~~including~~ the ~~duration, severity, scope and the necessary government actions to limit the spread of COVID-19. The~~ global coal industry data for the nine months ended September 30, ~~2021~~2022 presented herein may not be indicative of ~~the~~their ultimate ~~impacts of the COVID-19 pandemic given the various levels of response and unknown duration.~~

Within the seaborne metallurgical coal market, a combination of robust steel production, decade-high steel margins and tight coal availability have driven Australian spot prices to record levels. China’s unofficial ban on Australian coal remains in place and continues to support delivered China prices well above those of all other markets as domestic, Mongolian and seaborne coal supply from other sources continues to lag overall demand. The high prices being paid by China are incentivizing producers in Russia, the U.S. and Canada to supply China with incremental volumes, providing opportunities for Australia to supply customers typically serviced by these countries. The supply response to the record prices remains muted sending metallurgical coal prices higher. The Company believes energy shortages in some markets present a risk to industrial activity but the underlying market fundamentals remain constructive.impacts.

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Within the seaborne metallurgical coal market, the three months ended September 30, 2022 were characterized by ongoing volatility as a weakening global macroeconomic environment was counteracted by tight coal supply and continued trade flow disruptions following sanctions imposed on Russian coal imports. Steel prices drifted lower in the three months ended September 30, 2022, causing some steelmakers to implement small-scale output cuts. This is influencing short-term incremental metallurgical coal demand in some markets; however, it is being more than offset by a transition of demand from many steelmakers mitigating exposure to Russian coal imports by seeking additional volumes from other regions such as Australia, the U.S. and Canada. This is particularly so for PCI, where Russia accounts for approximately 35% of global traded volumes. China’s unofficial ban on Australian coal remains in place and continues to impede traditional trade flows. The Company believes energy shortages and the worsening inflationary environment present a risk to industrial activity in some markets, but the underlying market fundamentals remain constructive with continuing themes of supply tightness, resilient demand and further economic stimulus.

Within the seaborne thermal coal market, ~~a combination of tight supplies and elevated demand have driven Newcastle~~global thermal coal ~~pricing~~prices continue to ~~record levels. China’s domestic thermal~~remain at near-record levels, fueled by broader energy supply security concerns. These concerns have been driven by the Russian-Ukrainian conflict and the subsequent ban of Russian coal ~~supply remains hampered~~ by ~~heightened safety inspections and mine suspensions,~~European countries, as well as ~~flooding. Thermal electricity~~limited supply response out of Australia, Indonesia and South Africa due to weather and labor issues. In China, domestic coal production and renewable generation ~~in China has~~growth have been strong ~~year-to-date,~~during the nine months ended September 30, 2022, which has lowered import demand. In India, strong total generation demand and ~~the relaxation of China’s import controls combined with tight domestic supply~~growth in coal generation has ~~pushed~~supported increased import demand, ~~higher. Both India and China are experiencing rolling power outages, as multi-year low stockpile levels and high~~despite elevated domestic coal prices are pushing power plants into load shedding. In Europe, gas supply constraints and low wind generation have pushed standby coal plants to resume operation to help supply strong electricity demand. Despite the strong demand, the supply response has been muted, sendingproduction. Overall, global thermal coal ~~prices higher. Heavy rains in Indonesia, rail issues in Russia, production issues in Colombia~~markets remain turbulent as supply remains tight and ~~hampered domestic supply in China have all combined~~European coal importers look to ~~pressure the global thermal market.~~replace Russian coal.

In the United States, overall electricity demand increased more than 3% year-over-year, positively impacted by weather and economic activity. Through the ~~prior year economic impacts of the COVID-19 pandemic. Electricity~~nine months ended September 30, 2022, electricity generation from thermal coal has ~~notably improved~~declined year-over-year ~~as a result of higher natural gas prices~~due to coal conservation by utilities to build coal stocks, transportation issues impacting coal deliveries and ~~stronger overall electricity demand. This has positively impacted coal’s~~record renewable generation. Coal’s share of electricity generation ~~with a rise~~has declined slightly to approximately ~~23%~~20% for the nine months ended September 30, ~~2021,~~2022, while ~~causing natural gas’s~~wind and solar’s combined generation share has increased to 15%. Coal inventories have continued to decline tosince December 2021, with a decline of approximately ~~37%. Stronger coal use and a limited supply response in coal production has contributed to decreasing coal stockpile levels. Since December 2020, coal inventories have fallen by approximately 54~~19% or 18 million ~~tons, a 40% decline. Through~~tons. During the nine months ended September 30, ~~2021,~~2022, utility consumption of PRB coal ~~rose~~declined approximately ~~30%~~6% compared to the prior year period.

Financing ~~and Surety~~ Transactions

During ~~the fourth quarter of 2020 and~~ the first quarter of ~~2021,~~2022, Peabody issued convertible senior unsecured notes and used the ~~Company entered into a series~~proceeds of ~~interrelated agreements with its surety bond providers,~~ the ~~revolving lenders under its credit agreement and certain holders of its~~offering to retire nearer term higher cost senior secured ~~notes to extend a significant portion of its near-term~~debt. This both lowered the Company’s borrowing rates and extended debt maturities to ~~December 2024~~2028. Throughout 2022, Peabody has continued to reduce it outstanding debt. In addition, the Company has the positive intent and ability to ~~stabilize collateral~~make additional retirements of its higher cost senior secured debt within the next twelve months. All such amounts have been classified as current debt as of the balance sheet date.

High demand and tight supply for coal globally has resulted in a substantial rise in seaborne thermal coal prices during 2022, which has been amplified by the Russian-Ukrainian conflict, resulting in unprecedented upward volatility in Newcastle coal pricing since late February. As a result, Peabody posted additional cash margin of $335.8 million during the nine months ended September 30, 2022 to satisfy the margin requirements for its ~~existing surety bond portfolio.~~

During the second and third quarters of 2021, and continuing into the fourth quarter of 2021, the Company completed a series of additional financing transactions intended to improve its capital structure. These transactions included at-the-market common stock issuances for cash proceeds, common stock issuances for the retirement of long-term debt and the retirement of long-term debt primarily through open market purchases.derivative contracts.

Refer to the “Liquidity and Capital Resources” section contained within this Item 2 for a further discussion of these financing and ~~surety~~liquidity transactions.

~~Other~~North Goonyella Redevelopment

During ~~July 2021,~~the third quarter of 2022, the Company ~~executed transactions to sell~~initiated the redevelopment of its ~~closed Millennium~~North Goonyella Mine, a premium hard-coking coal longwall operation in Australia with over 70 million tons coal reserves. The project will utilize substantial existing infrastructure and ~~Wilkie Creek Mines, which reduced its closed~~equipment at the mine, reclamation liabilities and associated costs. Both mines were sold for minimal cash consideration and gains of $26.1 million and $24.6 million, respectively, were recorded in connection with the sales.

~~In September 2021, the Company reached~~including a new collective bargaining agreement with the UMWA on behalf of the hourly workforce of its Shoal Creek Mine. The Company idled the mine in the fourth quarter of 2020 due to market conditions. During the idle period the Company undertook activities, including300-meter longwall system, a coal handling preparation plant, ~~upgrade project,~~a dedicated rail loop for transport to the Dalrymple Bay Coal Terminal and an accommodation village with housing and service amenities for more than 400 workers. North Goonyella is anticipated to increase ~~productivity, lower costs~~the Company’s emphasis in its Seaborne Metallurgical Mining segment.

Initial redevelopment expenditures of $140 million have been approved by the Company’s board of directors and ~~improve yields from the operation~~include ventilation, equipment, conveyance and infrastructure updates in ~~the future. The Company expects~~anticipation of reaching development coal, subject to ~~begin production at Shoal Creek Mine~~regulatory approvals, in ~~the second half of the fourth quarter of 2021, with ramp up through~~ the first quarter of ~~2022.~~

~~The full workforce of~~2024. Cash flow from operations is expected to fund all redevelopment costs as the ~~Metropolitan Mine, which was idled~~Company continues to strengthen its balance sheet. Development costs in ~~December 2020, returned~~addition to the ~~mine~~current approved amount are estimated to be $240 million, with longwall operations expected to commence in May 2021. Development work at the mine has been ongoing and longwall production restarted late in the second quarter of 2021, with a ramp up to planned production levels in the fourth quarter of 2021. The underground workforce enterprise agreement expired in January 2021 and was renegotiated in October 2021.

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Other

In March 2022, the Company entered into a joint venture with unrelated partners to form R3 Renewables LLC (R3). R3 was formed with the intent of developing various sites, including certain non-mining land held by the Company in the U.S., for utility-scale photovoltaic solar generation and battery storage. During 2022, R3 has advanced efforts with potential customers, finalized its management team and commenced site evaluations with project developer Treaty Oak Clean Energy, LLC. The Company’s interest in R3 is accounted for as an equity method investment. The Company contributed $10.9 million to R3 and recorded an equity loss of $2.8 million from its operations during the nine months ended September 30, 2022.

In March 2022, Peabody Investments Corp., a wholly owned subsidiary of the Company, entered into a commitment agreement relating to one of its qualified pension plans (the Plan) with an insurer. Under the commitment agreement, the Plan purchased a group annuity contract for approximately $500 million and the insurer will reimburse the Plan for future benefit payments to be made to the Plan’s participants. Under the terms of this transaction, the Plan will continue to administer and pay the retirement benefits of Plan participants but will be reimbursed by the insurer for the payment of all benefits covered by the group annuity contract. In May 2022, the board of directors of Peabody Investments Corp. approved the termination of the Plan effective July 31, 2022. Refer to Note 10. “Pension and Postretirement Benefit Costs” to the accompanying unaudited condensed consolidated financial statements for a further discussion of this transaction.

Results of Operations

Three and Nine Months Ended September 30, ~~2021~~2022 Compared to the Three and Nine Months Ended September 30, ~~2020~~2021

Summary

The ~~Company’s revenues for the three months ended September 30, 2021 increased compared to the same period~~increases in 2020 ($8.0 million) due to the impacts of higher seaborne thermal and metallurgical pricing and higher seaborne metallurgical volumes, offset by net unrealized mark-to-market losses on derivative contracts related to forecasted sales and other financial trading ($222.3 million). Revenues for the nine months ended September 30, 2021 decreased compared to the same period in 2020 ($90.2 million) primarily due to the net unrealized mark-to-market losses on derivative contracts related to forecasted sales and other financial trading ($249.5 million) and lower sales volumes, partially offset by higher seaborne thermal and metallurgical pricing.

~~Results~~results from continuing operations, net of income taxes for the three and nine months ended September 30, ~~2021 increased~~2022 compared to the same ~~period~~periods in the prior year ($~~5.2 million)~~444.0 million and $836.2 million, respectively), were primarily driven by higher revenue ($663.5 million and $1,302.1 million, respectively) due to higher realized prices; improved results from equity affiliates ($~~26.4 million)~~11.7 million and $109.5 million, respectively); and lower interest expense ($11.7 million and $32.5 million, respectively). These favorable variances were partially offset by higher operating costs and expenses ($189.0 million and $519.6 million, respectively), which reflect increased sales sensitive costs and inflationary pressures for commodities, materials, services, repairs and labor; and net ~~gains from asset disposals in the current year ($23.3 million) driven by the sale of the Millennium Mine, net gains~~losses on early debt extinguishments in the current year ($~~16.0 million), net mark-to-market losses on actuarially determined liabilities recorded in the prior year period ($13.0 million)~~24.7 million and ~~lower postretirement health care costs ($11.4 million)~~$65.8 million, respectively). ~~These favorable variances were offset by higher operating costs and expenses ($98.5 million).~~

Results from continuing operations, net of income taxes for the nine months ended September 30, 2021 increased compared to the same period in the prior year ($1,579.1 million) primarily due to the asset impairment charges recorded in the prior year period ($1,418.1 million), lower operating costs and expenses driven by the sales volume decline as well as production efficiencies and other cost improvements ($43.3 million), lower depreciation, depletion and amortization ($43.2 million), improved results from equity affiliates ($37.1 million), lower postretirement health care costs ($34.3 million) and net gains on early debt extinguishments in the current year ($31.3 million). These favorable variances were offset by the unfavorable revenue variance described above and increased interest expense ($41.0 million) primarily resulting from fees and higher borrowing rates related to new debt arrangements entered into during the first quarter of 2021.

Adjusted EBITDA for the three and nine months ended September 30, ~~2021~~2022 reflected a year-over-year ~~increase~~increases of ~~$193.7~~$149.8 million and ~~$316.7~~$871.9 million, respectively.

As of September 30, 2021, the Company’s available liquidity was approximately $615 million. Refer to the “Liquidity and Capital Resources” section contained within this Item 2 for a further discussion of factors affecting the Company’s available liquidity.

Tons Sold

The following table presents tons sold by operating segment:


		Three Months Ended September 30,		(Decrease ) Increase to Volumes			Nine Months Ended September 30,		(Decrease ) Increase to Volumes				Three Months Ended September 30,		(Decrease) Increase to Volumes			Nine Months Ended September 30,		(Decrease) Increase to Volumes
		2021	2020	Tons	%		2021	2020	Tons	%			2022	2021	Tons	%		2022	2021	Tons	%
		(Tons in millions)					(Tons in millions)						(Tons in millions)					(Tons in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining	4.5	4.6	(0.1)	(2)	%	12.7	13.8	(1.1)	(8)	%	Seaborne Thermal Mining	3.7	4.5	(0.8)	(18)	%	11.5	12.7	(1.2)	(9)	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining	1.5	1.1	0.4	36	%	3.9	4.2	(0.3)	(7)	%	Seaborne Metallurgical Mining	1.8	1.5	0.3	20	%	4.6	3.9	0.7	18	%
Powder River Basin Mining	Powder River Basin Mining	22.7	23.6	(0.9)	(4)	%	65.9	65.0	0.9	1	%	Powder River Basin Mining	22.3	22.7	(0.4)	(2)	%	61.4	65.9	(4.5)	(7)	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining	4.5	4.8	(0.3)	(6)	%	12.3	13.5	(1.2)	(9)	%	Other U.S. Thermal Mining	4.8	4.5	0.3	7	%	13.4	12.3	1.1	9	%
Total tons sold from mining segments	Total tons sold from mining segments	33.2	34.1	(0.9)	(3)	%	94.8	96.5	(1.7)	(2)	%	Total tons sold from mining segments	32.6	33.2	(0.6)	(2)	%	90.9	94.8	(3.9)	(4)	%
Corporate and Other	Corporate and Other	0.5	0.6	(0.1)	(17)	%	1.9	2.1	(0.2)	(10)	%	Corporate and Other	0.1	0.5	(0.4)	(80)	%	0.3	1.9	(1.6)	(84)	%
Total tons sold	Total tons sold	33.7	34.7	(1.0)	(3)	%	96.7	98.6	(1.9)	(2)	%	Total tons sold	32.7	33.7	(1.0)	(3)	%	91.2	96.7	(5.5)	(6)	%

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Supplemental Financial Data

The following table presents supplemental financial data by operating segment:


		Three Months Ended September 30,				Increase (Decrease)				Nine Months Ended September 30,				Increase (Decrease)					Three Months Ended September 30,				Increase				Nine Months Ended September 30,				Increase (Decrease)
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
Revenues per Ton - Mining Operations (1)
Revenue per Ton - Mining Operations (1)																		Revenue per Ton - Mining Operations (1)
Seaborne Thermal	Seaborne Thermal	$	58.53	$	35.28	$	23.25	66	%	$	49.86	$	38.14	$	11.72	31	%	Seaborne Thermal	$	95.54	$	58.53	$	37.01	63	%	$	83.30	$	49.86	$	33.44	67	%
Seaborne Metallurgical	Seaborne Metallurgical	119.98		71.88		48.10		67	%	99.18		87.16		12.02		14	%	Seaborne Metallurgical	179.77		119.98		59.79		50	%	254.52		99.18		155.34		157	%
Powder River Basin	Powder River Basin	10.88		11.26		(0.38)		(3)	%	10.99		11.35		(0.36)		(3)	%	Powder River Basin	12.99		10.88		2.11		19	%	12.55		10.99		1.56		14	%
Other U.S. Thermal	Other U.S. Thermal	40.99		37.20		3.79		10	%	40.20		38.67		1.53		4	%	Other U.S. Thermal	54.58		40.99		13.59		33	%	51.62		40.20		11.42		28	%
Costs per Ton - Mining Operations (1)(2)	Costs per Ton - Mining Operations (1)(2)																	Costs per Ton - Mining Operations (1)(2)
Seaborne Thermal	Seaborne Thermal	$	35.09	$	27.59	$	7.50	27	%	$	33.72	$	29.58	$	4.14	14	%	Seaborne Thermal	$	49.22	$	35.09	$	14.13	40	%	$	45.22	$	33.72	$	11.50	34	%
Seaborne Metallurgical	Seaborne Metallurgical	81.61		96.87		(15.26)		(16)	%	96.98		110.20		(13.22)		(12)	%	Seaborne Metallurgical	114.32		81.61		32.71		40	%	124.86		96.98		27.88		29	%
Powder River Basin	Powder River Basin	9.25		7.93		1.32		17	%	9.28		9.15		0.13		1	%	Powder River Basin	11.29		9.25		2.04		22	%	11.84		9.28		2.56		28	%
Other U.S. Thermal	Other U.S. Thermal	30.99		26.52		4.47		17	%	30.02		29.60		0.42		1	%	Other U.S. Thermal	39.40		30.99		8.41		27	%	37.80		30.02		7.78		26	%
Adjusted EBITDA Margin per Ton - Mining Operations (1)(2)	Adjusted EBITDA Margin per Ton - Mining Operations (1)(2)																	Adjusted EBITDA Margin per Ton - Mining Operations (1)(2)
Seaborne Thermal	Seaborne Thermal	$	23.44	$	7.69	$	15.75	205	%	$	16.14	$	8.56	$	7.58	89	%	Seaborne Thermal	$	46.32	$	23.44	$	22.88	98	%	$	38.08	$	16.14	$	21.94	136	%
Seaborne Metallurgical	Seaborne Metallurgical	38.37		(24.99)		63.36		254	%	2.20		(23.04)		25.24		110	%	Seaborne Metallurgical	65.45		38.37		27.08		71	%	129.66		2.20		127.46		5,794	%
Powder River Basin	Powder River Basin	1.63		3.33		(1.70)		(51)	%	1.71		2.20		(0.49)		(22)	%	Powder River Basin	1.70		1.63		0.07		4	%	0.71		1.71		(1.00)		(58)	%
Other U.S. Thermal	Other U.S. Thermal	10.00		10.68		(0.68)		(6)	%	10.18		9.07		1.11		12	%	Other U.S. Thermal	15.18		10.00		5.18		52	%	13.82		10.18		3.64		36	%

(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.

~~Revenues~~Revenue

The following table presents ~~revenues~~revenue by reporting segment:


		Three Months Ended September 30,				Increase (Decrease) to Revenues				Nine Months Ended September 30,				Increase (Decrease) to Revenues					Three Months Ended September 30,				Increase to Revenue				Nine Months Ended September 30,				Increase (Decrease) to Revenue
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
		(Dollars in millions)								(Dollars in millions)									(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining	$	260.7	$	163.0	$	97.7	60	%	$	631.2	$	526.1	$	105.1	20	%	Seaborne Thermal Mining	$	353.2	$	260.7	$	92.5	35	%	$	959.3	$	631.2	$	328.1	52	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining	179.5		78.8		100.7		128	%	388.0		363.6		24.4		7	%	Seaborne Metallurgical Mining	310.7		179.5		131.2		73	%	1,165.8		388.0		777.8		200	%
Powder River Basin Mining	Powder River Basin Mining	247.1		264.8		(17.7)		(7)	%	724.1		737.2		(13.1)		(2)	%	Powder River Basin Mining	290.5		247.1		43.4		18	%	771.4		724.1		47.3		7	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining	184.6		179.8		4.8		3	%	496.0		524.1		(28.1)		(5)	%	Other U.S. Thermal Mining	261.4		184.6		76.8		42	%	689.4		496.0		193.4		39	%
Corporate and Other	Corporate and Other	(192.9)		(15.4)		(177.5)		(1,153)	%	(185.6)		(7.1)		(178.5)		(2,514)	%	Corporate and Other	126.7		(192.9)		319.6		166	%	(230.1)		(185.6)		(44.5)		(24)	%
Revenues		$	679.0	$	671.0	$	8.0	1	%	$	2,053.7	$	2,143.9	$	(90.2)	(4)	%
Revenue																		Revenue	$	1,342.5	$	679.0	$	663.5	98	%	$	3,355.8	$	2,053.7	$	1,302.1	63	%

Seaborne Thermal Mining. Segment ~~revenues~~revenue increased during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year due to favorable realized ~~coal pricing (three months, $105.5 million;~~prices ($154.1 million and $421.9 million, respectively), partially offset by unfavorable volumes ($61.6 million and $93.8 million, respectively) which were impacted by wet weather and a longwall move at the Wambo Underground Mine in the first half of 2022.

Seaborne Metallurgical Mining. Segment revenue increased during the three and nine months ~~$144.8 million)~~ended September 30, 2022 compared to the same periods in the prior year due to favorable realized prices at the Australian operations ($89.7 million and $559.7 million, respectively), ~~offset by unfavorable~~the resumption of sales at the Shoal Creek Mine ($33.1 million and $189.4 million, respectively) and favorable volume and mix variances ~~(three months, $7.8 million; nine months, $39.7 million)~~at the Australian operations ($8.4 million and $28.7 million, respectively).

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~~Seaborne Metallurgical~~Powder River Basin Mining. Segment ~~revenues~~revenue increased during the three and nine months ended September 30, 2022 compared to the same periods in the prior year due to favorable realized prices ($53.8 million and $105.0 million, respectively), offset by unfavorable volumes ($10.4 million and $57.7 million, respectively) resulting from rail performance issues.

Other U.S. Thermal Mining. Segment revenue increased during the three and nine months ended September 30, 2022 compared to the same periods in the prior year due to favorable realized prices ($65.7 million and $154.7 million, respectively) and favorable volumes ($11.1 million and $38.7 million, respectively).

Corporate and Other. Segment revenue increased during the three months ended September 30, ~~2021~~2022 compared to the same period in the prior year due to ~~favorable realized~~net unrealized mark-to-market gains on derivative contracts related to forecasted coal ~~pricing~~sales in the current year compared to net unrealized mark-to-market losses in the prior year ($~~67.0~~328.8 million) ~~and favorable volume and mix variances~~, partially offset by lower results from trading activities ($~~33.7~~10.9 million). Segment ~~revenues increased~~revenue decreased during the nine months ended September 30, ~~2021~~2022 compared to the same period in the prior year due to ~~favorable realized coal pricing~~lower results from trading activities ($52.3 million), partially offset by unfavorable volume and mix variances ($27.9 million). The unfavorable volume variances resulted from the Shoal Creek Mine being idled through the first nine months of 2021, the Metropolitan Mine being idled through the first quarter of 2021 and the closure of the Millennium Mine during the second quarter of 2020. These unfavorable volume variances were partially offset by improved demand at the Coppabella and Moorvale Mines.

~~Powder River Basin Mining.~~ Segment revenues decreased during the three months ended September 30, 2021 compared to the same period in the prior year primarily due to decreased production ($9.7 million) and unfavorable realized coal pricing ($8.0 million). Segment revenues decreased during the nine months ended September 30, 2021 compared to the same period in the prior year primarily due to unfavorable realized coal pricing ($19.3 million), partially offset by increased demand ($6.2 million).

~~Other U.S. Thermal Mining.~~ ~~Segment revenues increased during the three months ended September 30, 2021 compared to the same period in the prior year due to favorable realized pricing ($18.9~~74.6 million), offset by lower volumes attributable to decreased production and rail performance issues ($14.1 million). Segment revenues decreased during the nine months ended September 30, 2021 compared to the same period in the prior year primarily due to lower volumes attributable to decreased production and rail performance issues ($52.0 million), partially offset by favorable realized pricing ($23.9 million).

~~Corporate and Other.~~ ~~Segment revenues decreased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year primarily due to~~ net unrealized mark-to-market losses on derivative contracts related to forecasted coal sales ~~and other financial trading (three months, $222.3 million; nine months, $249.5~~($28.9 million)~~, partially offset by higher results from trading activities.~~.

Adjusted EBITDA

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


		Three Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA					Three Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
		(Dollars in millions)								(Dollars in millions)									(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining	$	104.4	$	35.3	$	69.1	196	%	$	204.3	$	118.1	$	86.2	73	%	Seaborne Thermal Mining	$	171.2	$	104.4	$	66.8	64	%	$	438.5	$	204.3	$	234.2	115	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining	57.4		(27.3)		84.7		310	%	8.6		(96.1)		104.7		109	%	Seaborne Metallurgical Mining	113.2		57.4		55.8		97	%	593.9		8.6		585.3		6,806	%
Powder River Basin Mining	Powder River Basin Mining	37.0		78.3		(41.3)		(53)	%	112.6		143.0		(30.4)		(21)	%	Powder River Basin Mining	37.9		37.0		0.9		2	%	43.5		112.6		(69.1)		(61)	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining	45.1		51.6		(6.5)		(13)	%	125.6		123.0		2.6		2	%	Other U.S. Thermal Mining	72.7		45.1		27.6		61	%	184.6		125.6		59.0		47	%
Corporate and Other	Corporate and Other	45.2		(42.5)		87.7		206	%	21.2		(132.4)		153.6		116	%	Corporate and Other	43.9		45.2		(1.3)		(3)	%	83.7		21.2		62.5		295	%
Adjusted EBITDA (1)	Adjusted EBITDA (1)	$	289.1	$	95.4	$	193.7	203	%	$	472.3	$	155.6	$	316.7	204	%	Adjusted EBITDA (1)	$	438.9	$	289.1	$	149.8	52	%	$	1,344.2	$	472.3	$	871.9	185	%

(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 Mining. Segment Adjusted EBITDA increased during the three and nine months ended September 30, ~~2021~~2022 compared to the same ~~period~~periods in the prior year as a result of higher realized prices net ~~coal pricing~~of sales sensitive costs ($~~97.5 million)~~141.3 million and $387.0 million, respectively), partially offset by lower volumes ($40.3 million and $26.7 million, respectively) due to wet weather impacts and unfavorable ~~mine sequencing~~operational costs ($27.5 million and $122.2 million, respectively) resulting from the impacts ~~($14.7 million), unfavorable sales volume variances ($5.1 million) and higher commodity pricing ($4.0 million). Segment Adjusted EBITDA increased during~~of wet weather, COVID-19-related staffing shortages, the ~~nine months ended September 30, 2021 compared to~~longwall move at the ~~same period~~Wambo Underground Mine in the ~~prior year as a result~~first half of ~~higher realized net coal pricing ($133.2 million)~~2022 and ~~cost improvements across the operations~~inflationary pressures on supplies and ~~product mix ($21.3 million). The increases were partially offset by unfavorable volume variances ($29.1 million) and unfavorable foreign currency impacts ($28.7 million).~~outside services.

Seaborne Metallurgical Mining. Segment Adjusted EBITDA increased during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year due to higher realized prices net ~~coal pricing (three months, $62.3 million; nine months, $48.8 million), cost improvements~~of sales sensitive costs at ~~certain mines (three months, $23.1 million; nine months, $71.9 million)~~the Australian operations ($66.3 million and $474.0 million, respectively) and favorable ~~volume variances (three~~volumes from the resumption of sales at the Shoal Creek Mine ($12.6 million and $111.1 million, respectively), offset by unfavorable operational costs at the Australian operations ($27.1 million and $13.5 million, respectively) resulting from higher costs for repair and maintenance and inflationary pressures.

Powder River Basin Mining. Segment Adjusted EBITDA increased during the three months ~~$3.5 million; nine months, $19.8~~ended September 30, 2022 compared to the same period in the prior year as a result of higher realized prices net of sales sensitive costs ($49.0 million), offset by the unfavorable ~~foreign currency~~ impacts ~~(three months, $2.2 million;~~of higher commodity pricing ($17.5 million), elevated overburden removal costs ($17.1 million) and higher costs for materials, services, repairs and labor ($9.1 million, respectively). Segment Adjusted EBITDA decreased during the nine months ~~$41.9~~ended September 30, 2022 compared to the same period in the prior year due to elevated overburden removal costs ($55.5 million); the unfavorable impacts of higher commodity pricing ($51.2 million) and higher costs for materials, services, repairs and labor ($41.9 million) both of which were impacted by inflationary pressures; and lower volumes ($13.2 million) resulting from rail performance issues. These decreases were partially offset by higher realized prices net of sales sensitive costs ($100.8 million).

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~~Powder River Basin~~Other U.S. Thermal Mining. Segment Adjusted EBITDA ~~decreased~~increased during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year due to ~~lower~~higher realized prices net ~~coal pricing (three months, $12.6 million; nine months, $17.7 million),~~of sales sensitive costs ($67.4 million and $159.3 million, respectively) and favorable volumes ($5.0 million and $17.9 million, respectively). These increases were offset by higher costs for materials, services, repairs and labor ~~(three months, $12.6 million; nine months, $16.7 million)~~($26.0 million and $73.7 million, respectively) and the unfavorable impacts of higher commodity pricing ~~(three months,~~($11.7 million and $36.2 million, respectively), both of which were impacted by inflationary pressures and elevated overburden removal costs ($6.2 million and $8.1 ~~million; nine months, $18.1 million). The decreases were offset by favorable mine sequencing impacts (nine months, $16.5 million).~~

~~Other U.S. Thermal Mining.~~ Segment Adjusted EBITDA decreased during the three months ended September 30, 2021 compared to the same period in the prior year due to higher costs for materials, services, repairs and labor ($12.9 million) and the unfavorable impacts of higher commodity pricing ($7.0 million), offset by higher realized net coal pricing ($17.9 million). Segment Adjusted EBITDA increased during the nine months ended September 30, 2021 compared to the same period in the prior year due to higher realized net coal pricing ($21.2 million) and favorable mine sequencing impacts ($16.9 million), offset by the unfavorable impacts of higher commodity pricing ($13.6 million)million, respectively).

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


		Three Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA					Three Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
		(Dollars in millions)								(Dollars in millions)									(Dollars in millions)								(Dollars in millions)
Middlemount (1)	Middlemount (1)	$	9.3	$	(11.1)	$	20.4	184	%	$	2.9	$	(27.2)	$	30.1	111	%	Middlemount (1)	$	27.9	$	9.3	$	18.6	200	%	$	121.9	$	2.9	$	119.0	4,103	%
Resource management activities (2)	Resource management activities (2)	(0.4)		1.0		(1.4)		(140)	%	3.9		9.8		(5.9)		(60)	%	Resource management activities (2)	5.2		(0.4)		5.6		1,400	%	22.5		3.9		18.6		477	%
Selling and administrative expenses	Selling and administrative expenses	(21.1)		(27.2)		6.1		22	%	(64.2)		(77.3)		13.1		17	%	Selling and administrative expenses	(19.6)		(21.1)		1.5		7	%	(64.5)		(64.2)		(0.3)		—	%
Other items, net (3)	Other items, net (3)	57.4		(5.2)		62.6		1,204	%	78.6		(37.7)		116.3		308	%	Other items, net (3)	30.4		57.4		(27.0)		(47)	%	3.8		78.6		(74.8)		(95)	%
Corporate and Other Adjusted EBITDA	Corporate and Other Adjusted EBITDA	$	45.2	$	(42.5)	$	87.7	206	%	$	21.2	$	(132.4)	$	153.6	116	%	Corporate and Other Adjusted EBITDA	$	43.9	$	45.2	$	(1.3)	(3)	%	$	83.7	$	21.2	$	62.5	295	%

(1)Middlemount’s results are before the impact of related changes in deferred tax asset valuation allowance and reserves and 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 ~~$17.9~~$12.9 million and ~~$8.6~~$10.4 million during the three months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively, and ~~$40.7~~$56.4 million and ~~$21.8~~$18.3 million during the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively.

(2)Includes gains (losses) on certain surplus coal reserve and surface land sales and property management costs and ~~revenues.~~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.

The ~~increase~~decrease in Corporate and Other Adjusted EBITDA during the three ~~and nine~~ months ended September 30, ~~2021~~2022 compared to the same ~~periods~~period in the prior year was driven by ~~favorable trading results (three months, $27.4 million; nine months, $39.1 million);~~ the gain recognized in the ~~current~~prior year on the sale of the Company’s Millennium Mine ~~(three and nine months, $26.1~~($26.1 million) as discussed in Note ~~14.~~15. “Other ~~Events”; a~~Events,” largely offset by the favorable variance in Middlemount’s results due to the ~~combined impacts~~impact of higher sales pricing ~~improved production~~($18.6 million) and ~~cost improvements; lower postretirement health care costs (three months, $11.2 million;~~gains on various land sales primarily in the U.S. ($3.9 million).

Corporate and Other Adjusted EBITDA benefited during the nine months ~~$33.6 million) primarily~~ended September 30, 2022 compared to the same period in the prior year from favorable variances in Middlemount’s results due to ~~changes made to one~~the impact of higher sales pricing ($119.0 million) and gains on various land sales in both the U.S. and Australia ($16.5 million). This benefit was offset by unfavorable trading results ($54.0 million) and the prior year gain on the sale of the ~~Company’s postretirement health care benefit plans announced in 2020; and lower containment and holding costs for the Company’s North Goonyella~~Millennium Mine ~~(nine months, $15.4 million).~~referenced above.

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~~Loss~~Income (Loss) From Continuing Operations, Net of Income Taxes

The following table presents ~~loss~~income (loss) from continuing operations, net of income taxes:


		Three Months Ended September 30,				Increase (Decrease) to Income				Nine Months Ended September 30,				Increase (Decrease) to Income					Three Months Ended September 30,				Increase (Decrease) to Income				Nine Months Ended September 30,				Increase (Decrease) to Income
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
		(Dollars in millions)								(Dollars in millions)									(Dollars in millions)								(Dollars in millions)
Adjusted EBITDA (1)	Adjusted EBITDA (1)	$	289.1	$	95.4	$	193.7	203	%	$	472.3	$	155.6	$	316.7	204	%	Adjusted EBITDA (1)	$	438.9	$	289.1	$	149.8	52	%	$	1,344.2	$	472.3	$	871.9	185	%
Depreciation, depletion and amortization	Depreciation, depletion and amortization	(77.9)		(72.2)		(5.7)		(8)	%	(223.3)		(266.5)		43.2		16	%	Depreciation, depletion and amortization	(80.7)		(77.9)		(2.8)		(4)	%	(227.4)		(223.3)		(4.1)		(2)	%
Asset retirement obligation expenses	Asset retirement obligation expenses	(14.3)		(14.3)		—		—	%	(45.3)		(46.0)		0.7		2	%	Asset retirement obligation expenses	(13.1)		(14.3)		1.2		8	%	(40.8)		(45.3)		4.5		10	%
Restructuring charges	Restructuring charges	(1.7)		(8.1)		6.4		79	%	(5.9)		(31.1)		25.2		81	%	Restructuring charges	(1.0)		(1.7)		0.7		41	%	(2.8)		(5.9)		3.1		53	%
Transaction costs related to joint ventures		—		(6.0)		6.0		100	%	—		(23.1)		23.1		100	%

Asset impairment	Asset impairment	—		—		—		n.m.		—		(1,418.1)		1,418.1		100	%	Asset impairment	(1.7)		—		(1.7)		n.m.		(1.7)		—		(1.7)		n.m.

Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	6.4		0.5		5.9		1,180	%	8.4		1.6		6.8		425	%	Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	0.5		6.4		(5.9)		(92)	%	1.7		8.4		(6.7)		(80)	%
Interest expense	Interest expense	(45.5)		(34.9)		(10.6)		(30)	%	(143.3)		(102.3)		(41.0)		(40)	%	Interest expense	(33.8)		(45.5)		11.7		26	%	(110.8)		(143.3)		32.5		23	%
Net gain on early debt extinguishment		16.0		—		16.0		n.m.		31.3		—		31.3		n.m.
Net (loss) gain on early debt extinguishment																		Net (loss) gain on early debt extinguishment	(8.7)		16.0		(24.7)		(154)	%	(34.5)		31.3		(65.8)		(210)	%
Interest income	Interest income	1.4		1.6		(0.2)		(13)	%	4.2		7.1		(2.9)		(41)	%	Interest income	4.9		1.4		3.5		250	%	6.3		4.2		2.1		50	%
Net mark-to-market adjustment on actuarially determined liabilities		—		(13.0)		13.0		100	%	—		(13.0)		13.0		100	%
Unrealized losses on derivative contracts related to forecasted sales		(238.4)		(16.1)		(222.3)		(1,381)	%	(264.0)		(11.3)		(252.7)		(2,236)	%
Unrealized gains (losses) on foreign currency option contracts		0.6		0.7		(0.1)		(14)	%	(8.2)		3.6		(11.8)		(328)	%

Unrealized gains (losses) on derivative contracts related to forecasted sales																		Unrealized gains (losses) on derivative contracts related to forecasted sales	90.4		(238.4)		328.8		138	%	(235.1)		(264.0)		28.9		11	%
Unrealized (losses) gains on foreign currency option contracts																		Unrealized (losses) gains on foreign currency option contracts	(1.4)		0.6		(2.0)		(333)	%	(4.4)		(8.2)		3.8		46	%
Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition	1.0		1.5		(0.5)		(33)	%	3.2		6.8		(3.6)		(53)	%	Take-or-pay contract-based intangible recognition	0.8		1.0		(0.2)		(20)	%	2.2		3.2		(1.0)		(31)	%
Income tax benefit (provision)		3.7		0.1		3.6		3,600	%	10.3		(2.7)		13.0		481	%
Loss from continuing operations, net of income taxes		$	(59.6)	$	(64.8)	$	5.2	8	%	$	(160.3)	$	(1,739.4)	$	1,579.1	91	%
Income tax (provision) benefit																		Income tax (provision) benefit	(10.7)		3.7		(14.4)		(389)	%	(21.0)		10.3		(31.3)		(304)	%
Income (loss) from continuing operations, net of income taxes																		Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	444.0	745	%	$	675.9	$	(160.3)	$	836.2	522	%

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


		Three Months Ended September 30,				(Decrease) Increase to Income				Nine Months Ended September 30,				(Decrease) Increase to Income					Three Months Ended September 30,				(Decrease) Increase to Income				Nine Months Ended September 30,				(Decrease) Increase to Income
		2021		2020		$		%		2021		2020		$		%			2022		2021		$		%		2022		2021		$		%
		(Dollars in millions)								(Dollars in millions)									(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining	$	(25.8)	$	(20.2)	$	(5.6)	(28)	%	$	(73.8)	$	(62.9)	$	(10.9)	(17)	%	Seaborne Thermal Mining	$	(28.8)	$	(25.8)	$	(3.0)	(12)	%	$	(79.0)	$	(73.8)	$	(5.2)	(7)	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining	(19.6)		(20.0)		0.4		2	%	(53.5)		(65.3)		11.8		18	%	Seaborne Metallurgical Mining	(22.6)		(19.6)		(3.0)		(15)	%	(64.5)		(53.5)		(11.0)		(21)	%
Powder River Basin Mining	Powder River Basin Mining	(11.9)		(10.9)		(1.0)		(9)	%	(31.8)		(74.4)		42.6		57	%	Powder River Basin Mining	(11.6)		(11.9)		0.3		3	%	(31.4)		(31.8)		0.4		1	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining	(17.0)		(16.9)		(0.1)		(1)	%	(50.2)		(53.9)		3.7		7	%	Other U.S. Thermal Mining	(15.7)		(17.0)		1.3		8	%	(45.1)		(50.2)		5.1		10	%
Corporate and Other	Corporate and Other	(3.6)		(4.2)		0.6		14	%	(14.0)		(10.0)		(4.0)		(40)	%	Corporate and Other	(2.0)		(3.6)		1.6		44	%	(7.4)		(14.0)		6.6		47	%
Total	Total	$	(77.9)	$	(72.2)	$	(5.7)	(8)	%	$	(223.3)	$	(266.5)	$	43.2	16	%	Total	$	(80.7)	$	(77.9)	$	(2.8)	(4)	%	$	(227.4)	$	(223.3)	$	(4.1)	(2)	%

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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 mining segments:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
Seaborne Thermal Mining	Seaborne Thermal Mining	$	2.20	$	1.78	$	2.18	$	1.92	Seaborne Thermal Mining	$	2.79	$	2.20	$	2.57	$	2.18
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining	1.14		1.83		1.06		2.24		Seaborne Metallurgical Mining	2.04		1.14		2.55		1.06
Powder River Basin Mining	Powder River Basin Mining	0.24		0.23		0.24		0.59		Powder River Basin Mining	0.32		0.24		0.32		0.24
Other U.S. Thermal Mining	Other U.S. Thermal Mining	1.18		1.11		1.16		1.05		Other U.S. Thermal Mining	1.26		1.18		1.23		1.16

Depreciation, depletion and amortization expense decreased during the nine months ended September 30, 2021 compared to the same period in the prior year primarily due to the impact of the asset impairment recorded at the North Antelope Rochelle Mine during the second quarter of 2020 (nine months, $45.3 million). The ~~decrease~~increase in the weighted-average depletion rate per ton for the Seaborne Thermal Mining segment during the three and nine months ended September 30, 2022 compared to the same periods in the prior year reflects the impact of volume and mix variances across the segment. The increase in the Seaborne Metallurgical Mining segment during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year reflects the ~~volume~~resumption of sales at the Shoal Creek Mine in December 2021.

Changes in Deferred Tax Asset Valuation Allowance and ~~mix variances which impacted the Company’s revenues as described above.~~Reserves and Amortization of Basis Difference Related to Equity Affiliates. The ~~decrease in the weighted-average depletion rate per ton~~income reflected for the ~~Powder River Basin Mining segment during the~~three and nine months ended September 30, 2021 ~~compared~~includes the release of valuation allowance previously recorded on Middlemount’s deferred tax assets as a result of taxable income generated during 2021. As of December 31, 2021, no valuation allowance remained related to Middlemount’s deferred tax assets so there is no release reflected in 2022. The current year income activity relates only to the ~~same period~~amortization of basis differences which is comparable to prior periods.

Interest Expense. The decrease in ~~the prior year reflects the asset impairment recorded during the second quarter of 2020.~~

~~Restructuring Charges.~~ ~~Restructuring charges decreased~~interest expense during the three and nine months ended September 30, 2022 primarily reflects the impacts of debt retirements completed by the Company during 2022 and 2021 ~~compared to the same periods in the~~and prior year ~~as the result of workforce reductions made across the organization during the prior year.~~

~~Transaction Costs Related to Joint Ventures.~~ ~~The charges recorded during the prior year period~~fees related to ~~the proposed PRB Colorado joint venture with Arch Resources, Inc. which was terminated during the third quarter~~a series of ~~2020.~~

~~Asset Impairment.~~ ~~During the nine months ended September 30, 2020,~~refinancing transactions completed by the Company ~~recognized $1,418.1 million in aggregate asset impairment charges related to the fair value of its North Antelope Rochelle Mine in its Powder River Basin Mining segment~~(nine months, $10.6 million) as ~~discussed~~further described in Note ~~8. “Property, Plant, Equipment and Mine Development”~~9. “Long-term Debt” to the accompanying unaudited condensed consolidated financial ~~statements.~~statements and Note 11. “Long-term Debt” to the Annual Report on Form 10-K for the year ended December 31, 2021.

~~Interest Expense.~~Net (Loss) Gain on Early Debt Extinguishment. ~~Interest expense increased~~The losses recognized during the three and nine months ended September 30, ~~2021 compared~~2022 were primarily related to the ~~same periods in the prior year as the result~~redemption of ~~a series of refinancing transactions completed by the Company~~existing notes during the ~~first quarter of 2021~~periods as ~~described~~further discussed in Note ~~11.~~9. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements.

~~Net Gain on Early Debt Extinguishment.~~ The gain recognized during the three and nine months ended September 30, 2021 was primarily related to debt retirements made through various open market purchases during the second and third quarters of 2021 and the senior notes exchange completed during the first quarter of 2021 as further discussed in Note 11. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements.

~~Net Mark-to-Market Adjustment on Actuarially Determined Liabilities.~~ The expense recorded during the three and nine months ended September 30, 2020 related to changes made to one of the Company’s postretirement health care benefit plans which triggered a remeasurement event.

Unrealized ~~Losses~~Gains (Losses) on Derivative Contracts Related to Forecasted Sales. Unrealized ~~losses~~gains (losses) primarily relate to mark-to-market activity on ~~derivatives~~derivative contracts related to forecasted coal sales. For additional information, refer to Note 7.6. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

Unrealized (Losses) Gains ~~(Losses)~~ on Foreign Currency Option Contracts. Unrealized (losses) gains ~~(losses)~~ primarily relate to mark-to-market activity on foreign currency option contracts. For additional information, refer to Note 7.6. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

Income Tax ~~Benefit~~ (Provision) Benefit. . The increase in the income tax ~~benefit for~~provision during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year was primarily due to ~~differences~~an increase in ~~forecasted~~ taxable income, ~~and~~partially offset by an increase in the benefit related to the remeasurement of foreign income tax accounts. The Company expects to utilize substantial net operating losses in Australia and the U.S. in 2022 based on estimated pretax income. Refer to Note ~~10.~~8. “Income Taxes” to the accompanying unaudited condensed consolidated financial statements for additional information.

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Net ~~Loss~~Income (Loss) Attributable to Common Stockholders

The following table presents net ~~loss~~income (loss) attributable to common stockholders:

Three Months Ended September 30, Increase
to Income Nine Months Ended September 30, Increase
to Income
2021 2020 $ % 2021 2020 $ %
(Dollars in millions) (Dollars in millions)
Loss from continuing operations, net of income taxes $ (59.6) $ (64.8) $ 5.2 8 % $ (160.3) $ (1,739.4) $ 1,579.1 91 %
Income (loss) from discontinued operations, net of income taxes 24.3 (2.3) 26.6 1,157 % 20.0 (6.8) 26.8 394 %
Net loss (35.3) (67.1) 31.8 47 % (140.3) (1,746.2) 1,605.9 92 %
Less: Net income (loss) attributable to noncontrolling interests 8.9 0.1 8.8 8,800 % 12.6 (5.1) 17.7 347 %
Net loss attributable to common stockholders $ (44.2) $ (67.2) $ 23.0 34 % $ (152.9) $ (1,741.1) $ 1,588.2 91 %


	Three Months Ended September 30,				Increase (Decrease) to Income				Nine Months Ended September 30,				Increase (Decrease) to Income
	2022		2021		$		%		2022		2021		$		%
	(Dollars in millions)								(Dollars in millions)
Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	444.0	745	%	$	675.9	$	(160.3)	$	836.2	522	%
(Loss) income from discontinued operations, net of income taxes	(0.8)		24.3		(25.1)		(103)	%	(2.3)		20.0		(22.3)		(112)	%
Net income (loss)	383.6		(35.3)		418.9		1,187	%	673.6		(140.3)		813.9		580	%
Less: Net income attributable to noncontrolling interests	8.5		8.9		(0.4)		(4)	%	8.5		12.6		(4.1)		(33)	%
Net income (loss) attributable to common stockholders	$	375.1	$	(44.2)	$	419.3	949	%	$	665.1	$	(152.9)	$	818.0	535	%

(Loss) Income ~~(Loss)~~ from Discontinued Operations, Net of Income ~~Taxes~~Taxes. . The ~~increase~~decrease in the results from discontinued operations ~~for~~during the three and nine months ended September 30, ~~2021~~2022 compared to the same periods in the prior year was primarily due to the prior year gain of $24.6 million recognized on the sale of the Wilkie Creek Mine. Refer to Note ~~14.~~15. “Other Events” to the accompanying unaudited condensed consolidated financial statements for additional information.

Diluted Earnings per Share (EPS)

The following table presents diluted EPS:

Three Months Ended September 30, Increase
to EPS Nine Months Ended September 30, Increase
to EPS
2021 2020 $ % 2021 2020 $ %
Diluted EPS attributable to common stockholders:
Loss from continuing operations $ (0.60) $ (0.66) $ 0.06 9 % $ (1.65) $ (17.76) $ 16.11 91 %
Income (loss) from discontinued operations 0.22 (0.03) 0.25 833 % 0.19 (0.07) 0.26 371 %
Net loss attributable to common stockholders $ (0.38) $ (0.69) $ 0.31 45 % $ (1.46) $ (17.83) $ 16.37 92 %


	Three Months Ended September 30,				Increase (Decrease) to EPS				Nine Months Ended September 30,				Increase (Decrease) to EPS
	2022		2021		$		%		2022		2021		$		%
Diluted EPS attributable to common stockholders:
Income (loss) from continuing operations	$	2.34	$	(0.60)	$	2.94	490	%	$	4.33	$	(1.65)	$	5.98	362	%
(Loss) income from discontinued operations	(0.01)		0.22		(0.23)		(105)	%	(0.02)		0.19		(0.21)		(111)	%
Net income (loss) attributable to common stockholders	$	2.33	$	(0.38)	$	2.71	713	%	$	4.31	$	(1.46)	$	5.77	395	%

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 ~~114.9~~161.9 million and ~~97.9~~114.9 million for the three months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively, and ~~104.9~~155.6 million and ~~97.6~~104.9 million for the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, respectively.

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Reconciliation of Non-GAAP Financial Measures

Adjusted EBITDA is defined as ~~loss~~income (loss) 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 September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(Dollars in millions)									(Dollars in millions)
Loss from continuing operations, net of income taxes		$	(59.6)	$	(64.8)	$	(160.3)	$	(1,739.4)
Income (loss) from continuing operations, net of income taxes										Income (loss) from continuing operations, net of income taxes	$	384.4	$	(59.6)	$	675.9	$	(160.3)
Depreciation, depletion and amortization	Depreciation, depletion and amortization	77.9		72.2		223.3		266.5		Depreciation, depletion and amortization	80.7		77.9		227.4		223.3
Asset retirement obligation expenses	Asset retirement obligation expenses	14.3		14.3		45.3		46.0		Asset retirement obligation expenses	13.1		14.3		40.8		45.3
Restructuring charges	Restructuring charges	1.7		8.1		5.9		31.1		Restructuring charges	1.0		1.7		2.8		5.9
Transaction costs related to joint ventures		—		6.0		—		23.1

Asset impairment	Asset impairment	—		—		—		1,418.1		Asset impairment	1.7		—		1.7		—

Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	(6.4)		(0.5)		(8.4)		(1.6)		Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	(0.5)		(6.4)		(1.7)		(8.4)
Interest expense	Interest expense	45.5		34.9		143.3		102.3		Interest expense	33.8		45.5		110.8		143.3
Net gain on early debt extinguishment		(16.0)		—		(31.3)		—
Net loss (gain) on early debt extinguishment										Net loss (gain) on early debt extinguishment	8.7		(16.0)		34.5		(31.3)
Interest income	Interest income	(1.4)		(1.6)		(4.2)		(7.1)		Interest income	(4.9)		(1.4)		(6.3)		(4.2)
Net mark-to-market adjustment on actuarially determined liabilities		—		13.0		—		13.0
Unrealized losses on derivative contracts related to forecasted sales		238.4		16.1		264.0		11.3
Unrealized (gains) losses on foreign currency option contracts		(0.6)		(0.7)		8.2		(3.6)

Unrealized (gains) losses on derivative contracts related to forecasted sales										Unrealized (gains) losses on derivative contracts related to forecasted sales	(90.4)		238.4		235.1		264.0
Unrealized losses (gains) on foreign currency option contracts										Unrealized losses (gains) on foreign currency option contracts	1.4		(0.6)		4.4		8.2
Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition	(1.0)		(1.5)		(3.2)		(6.8)		Take-or-pay contract-based intangible recognition	(0.8)		(1.0)		(2.2)		(3.2)
Income tax (benefit) provision		(3.7)		(0.1)		(10.3)		2.7
Income tax provision (benefit)										Income tax provision (benefit)	10.7		(3.7)		21.0		(10.3)
Total Adjusted EBITDA	Total Adjusted EBITDA	$	289.1	$	95.4	$	472.3	$	155.6	Total Adjusted EBITDA	$	438.9	$	289.1	$	1,344.2	$	472.3

~~Revenues~~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 September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Operating costs and expenses	$	838.4	$	649.4	$	2,363.0	$	1,843.4
Unrealized (losses) gains on foreign currency option contracts	(1.4)		0.6		(4.4)		(8.2)
Take-or-pay contract-based intangible recognition	0.8		1.0		2.2		3.2

Net periodic benefit credit, excluding service cost	(12.2)		(8.6)		(36.7)		(26.0)
Total Reporting Segment Costs	$	825.6	$	642.4	$	2,324.1	$	1,812.4

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(Dollars in millions)
Seaborne Thermal Mining	$	182.0	$	156.3	$	520.8	$	426.9
Seaborne Metallurgical Mining	197.5		122.1		571.9		379.4
Powder River Basin Mining	252.6		210.1		727.9		611.5
Other U.S. Thermal Mining	188.7		139.5		504.8		370.4
Corporate and Other	4.8		14.4		(1.3)		24.2
Total Reporting Segment Costs	$	825.6	$	642.4	$	2,324.1	$	1,812.4

Table of Contents

Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to ~~revenues~~revenue by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to ~~Revenues~~Revenue per Ton less Adjusted EBITDA Margin per ~~Ton,~~Ton.

The following tables present tons sold, revenue, Reporting Segment Costs and ~~are reconciled to operating costs and expenses as follows:~~Adjusted EBITDA by mining segment:

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Operating costs and expenses $ 649.4 $ 550.9 $ 1,843.4 $ 1,886.7
Unrealized gains (losses) on foreign currency option contracts 0.6 0.7 (8.2) 3.6
Take-or-pay contract-based intangible recognition 1.0 1.5 3.2 6.8
Net periodic benefit (credit) costs, excluding service cost (8.6) 2.8 (26.0) 8.3
Total Reporting Segment Costs $ 642.4 $ 555.9 $ 1,812.4 $ 1,905.4


	Three Months Ended September 30, 2022
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	3.7		1.8		22.3		4.8

Revenue	$	353.2	$	310.7	$	290.5	$	261.4
Reporting Segment Costs	182.0		197.5		252.6		188.7
Adjusted EBITDA	$	171.2	$	113.2	$	37.9	$	72.7

Revenue per Ton	$	95.54	$	179.77	$	12.99	$	54.58
Costs per Ton	49.22		114.32		11.29		39.40
Adjusted EBITDA Margin per Ton	$	46.32	$	65.45	$	1.70	$	15.18


	Three Months Ended September 30, 2021
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	4.5		1.5		22.7		4.5

Revenue	$	260.7	$	179.5	$	247.1	$	184.6
Reporting Segment Costs	156.3		122.1		210.1		139.5
Adjusted EBITDA	$	104.4	$	57.4	$	37.0	$	45.1

Revenue per Ton	$	58.53	$	119.98	$	10.88	$	40.99
Costs per Ton	35.09		81.61		9.25		30.99
Adjusted EBITDA Margin per Ton	$	23.44	$	38.37	$	1.63	$	10.00

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

Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
(Dollars in millions)
Seaborne Thermal Mining $ 156.3 $ 127.7 $ 426.9 $ 408.0
Seaborne Metallurgical Mining 122.1 106.1 379.4 459.7
Powder River Basin Mining 210.1 186.5 611.5 594.2
Other U.S. Thermal Mining 139.5 128.2 370.4 401.1
Corporate and Other 14.4 7.4 24.2 42.4
Total Reporting Segment Costs $ 642.4 $ 555.9 $ 1,812.4 $ 1,905.4

~~The following tables present tons sold, revenues, Reporting Segment Costs and Adjusted EBITDA by mining segment:~~

Three Months Ended September 30, 2021
Seaborne Thermal Mining Seaborne Metallurgical Mining Powder River Basin Mining Other U.S. Thermal Mining
(Amounts in millions, except per ton data)
Tons sold 4.5 1.5 22.7 4.5
Revenues $ 260.7 $ 179.5 $ 247.1 $ 184.6
Reporting Segment Costs 156.3 122.1 210.1 139.5
Adjusted EBITDA $ 104.4 $ 57.4 $ 37.0 $ 45.1
Revenues per Ton $ 58.53 $ 119.98 $ 10.88 $ 40.99
Costs per Ton 35.09 81.61 9.25 30.99
Adjusted EBITDA Margin per Ton $ 23.44 $ 38.37 $ 1.63 $ 10.00

Three Months Ended September 30, 2020
Seaborne Thermal Mining Seaborne Metallurgical Mining Powder River Basin Mining Other U.S. Thermal Mining
(Amounts in millions, except per ton data)
Tons sold 4.6 1.1 23.6 4.8
Revenues $ 163.0 $ 78.8 $ 264.8 $ 179.8
Reporting Segment Costs 127.7 106.1 186.5 128.2
Adjusted EBITDA $ 35.3 $ (27.3) $ 78.3 $ 51.6
Revenues per Ton $ 35.28 $ 71.88 $ 11.26 $ 37.20
Costs per Ton 27.59 96.87 7.93 26.52
Adjusted EBITDA Margin per Ton $ 7.69 $ (24.99) $ 3.33 $ 10.68

~~Table of Contents~~

Nine Months Ended September 30, 2021
Seaborne Thermal Mining Seaborne Metallurgical Mining Powder River Basin Mining Other U.S. Thermal Mining
(Amounts in millions, except per ton data)
Tons sold 12.7 3.9 65.9 12.3
Revenues $ 631.2 $ 388.0 $ 724.1 $ 496.0
Reporting Segment Costs 426.9 379.4 611.5 370.4
Adjusted EBITDA $ 204.3 $ 8.6 $ 112.6 $ 125.6
Revenues per Ton $ 49.86 $ 99.18 $ 10.99 $ 40.20
Costs per Ton 33.72 96.98 9.28 30.02
Adjusted EBITDA Margin per Ton $ 16.14 $ 2.20 $ 1.71 $ 10.18

Nine Months Ended September 30, 2020
Seaborne Thermal Mining Seaborne Metallurgical Mining Powder River Basin Mining Other U.S. Thermal Mining
(Amounts in millions, except per ton data)
Tons sold 13.8 4.2 65.0 13.5
Revenues $ 526.1 $ 363.6 $ 737.2 $ 524.1
Reporting Segment Costs 408.0 459.7 594.2 401.1
Adjusted EBITDA $ 118.1 $ (96.1) $ 143.0 $ 123.0
Revenues per Ton $ 38.14 $ 87.16 $ 11.35 $ 38.67
Costs per Ton 29.58 110.20 9.15 29.60
Adjusted EBITDA Margin per Ton $ 8.56 $ (23.04) $ 2.20 $ 9.07


	Nine Months Ended September 30, 2022
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	11.5		4.6		61.4		13.4

Revenue	$	959.3	$	1,165.8	$	771.4	$	689.4
Reporting Segment Costs	520.8		571.9		727.9		504.8
Adjusted EBITDA	$	438.5	$	593.9	$	43.5	$	184.6

Revenue per Ton	$	83.30	$	254.52	$	12.55	$	51.62
Costs per Ton	45.22		124.86		11.84		37.80
Adjusted EBITDA Margin per Ton	$	38.08	$	129.66	$	0.71	$	13.82


	Nine Months Ended September 30, 2021
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	12.7		3.9		65.9		12.3

Revenue	$	631.2	$	388.0	$	724.1	$	496.0
Reporting Segment Costs	426.9		379.4		611.5		370.4
Adjusted EBITDA	$	204.3	$	8.6	$	112.6	$	125.6

Revenue per Ton	$	49.86	$	99.18	$	10.99	$	40.20
Costs per Ton	33.72		96.98		9.28		30.02
Adjusted EBITDA Margin per Ton	$	16.14	$	2.20	$	1.71	$	10.18

Free Cash Flow is defined as net cash ~~used in~~provided by (used in) operating activities ~~less~~plus net cash ~~used in~~provided by (used in) investing activities and excludes cash outflows related to business combinations. See the table below for a reconciliation of Free Cash Flow to its most comparable measure under U.S. GAAP.

Nine Months Ended September 30,
2021 2020
(Dollars in millions)
Net cash used in operating activities $ (18.4) $ (32.1)
Net cash used in investing activities (119.7) (159.4)
Free Cash Flow $ (138.1) $ (191.5)


	Nine Months Ended September 30,
	2022		2021
	(Dollars in millions)
Net cash provided by (used in) operating activities	$	504.1	$	(18.4)
Net cash provided by (used in) investing activities	61.1		(119.7)

Free Cash Flow	$	565.2	$	(138.1)

Regulatory Update

Other than as described in the following section, there were no significant changes to the Company’s regulatory matters subsequent to December 31, ~~2020.~~2021. Information regarding the Company’s regulatory matters is outlined in Part I, Item 1. “Business” in its Annual Report on Form 10-K for the year ended December 31, ~~2020.~~

~~Regulatory Matters - U.S.~~

~~Clean Air Act (CAA). The CAA, enacted in 1970, and comparable state and tribal laws that regulate air emissions affect the Company’s U.S. coal mining operations both directly and indirectly.~~2021.

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~~The CAA requires~~Regulatory Matters - U.S.

EPA Regulation of Greenhouse Gas Emissions from Existing Fossil Fuel-Fired EGUs. On October 23, 2015, the United States Environmental Protection Agency (EPA) published a final rule in the Federal Register regulating greenhouse gas emissions from existing fossil fuel-fired electric generation units (EGUs) under Section 111(d) of the Clean Air Act (CAA) (80 Fed. Reg. 64,662 (Oct. 23, 2015)). The rule (known as the Clean Power Plan or CPP) established emission guidelines for states to follow in developing plans to reduce greenhouse gas emissions (GHGs) from existing fossil fuel-fired EGUs. The CPP required that the states individually or collectively create systems that would reduce carbon emissions from any EGU located within their borders by 28% in 2025 and 32% in 2030 (compared with a 2005 baseline).

The EPA subsequently proposed to repeal the CPP and in August 2018 issued a proposed rule to replace the CPP with the Affordable Clean Energy (ACE) Rule. In June 2019, the EPA issued a combined package that finalized the CPP repeal rule as well as the replacement rule, ACE. The ACE rule set emissions guidelines for greenhouse gas emissions from existing EGUs based on a determination that efficiency heat rate improvements constitute the Best System of Emission Reduction (BSER). Numerous petitions for review challenging the ACE Rule were filed in the United States Court of Appeals for the D.C. Circuit (D.C. Circuit) and subsequently consolidated. In January 2021, a 3-judge panel of the D.C. Circuit vacated and remanded the ACE Rule to the EPA, including its repeal of the CPP and amendments to the implementing regulations that extended the compliance timeline.

On October 29, 2021, the Supreme Court of the United States (Supreme Court) granted certiorari in four consolidated matters seeking review of the D.C. Circuit’s opinion vacating the ACE rule and invalidating the repeal of the CPP. On June 30, 2022, the Supreme Court issued its opinion in West Virginia v. EPA, No. 20-1530. The Supreme Court ruled that the EPA does not have Congressional authority under section 111(d) of the CAA to limit emissions at existing power plants through generation shifting to other fuels and/or renewable energy, but still can regulate emissions at plants by emissions reductions technologies as the EPA has done in the past. The D.C. Circuit’s opinion was reversed and remanded, leaving neither the CPP or the ACE Rule in effect. Thus, it will be necessary for the EPA to initiate new rulemaking in order to control GHGs from EGUs using section 111(d) of the CAA. The EPA tentatively plans to propose emission guidelines for EGUs in the spring of 2023. The Company will continue to monitor EPA rulemaking in this regard.

National Ambient Air Quality Standards (NAAQS). The CAA requires the EPA to review national ambient air quality standards (NAAQS) every five years to determine whether revision to current standards are appropriate. As part of this recurring review process, the EPA in 2020 proposed to retain the ozone ~~standards~~NAAQS promulgated in 2015, including ~~current~~both the primary (public health) and secondary ~~standards, and~~(public welfare) standards. The EPA subsequently promulgated final standards to this effect. ~~Fifteen~~In 2021, fifteen states and other petitioners ~~have~~ filed a petition for review of the rule in the ~~United States Court of Appeals for the~~ D.C. ~~Circuit (D.C. Circuit).~~Circuit. The litigation is currently in abeyance following a motion filed by the EPA to allow for review of the standards.

The EPA also proposed in 2020 to retain the particulate matter (PM) ~~standards~~NAAQS last revised in 2012. On December 18, 2020, the EPA issued a final rule to retain both the primary annual and 24-hour PM standards for fine particulate matter (PM2.5) and the primary 24-hour standard for coarse particulate matter (PM10) and secondary PM10 standards. This rule has also been challenged in the D.C. Circuit by several states and environmental organizations. The case is currently in abeyance following a motion filed by the EPA to allow for review of the standards.

More stringent PM or ozone standards would require new state implementation plans to be developed and filed with the EPA and may trigger additional control technology for mining equipment or result in additional challenges to permitting and expansion efforts. This could also be the case with respect to other NAAQS for nitrogen dioxide (NO2) and sulfur dioxide (SO2), although these standards are not subject to a statutorily-required review until 2023 for NO2 and 2024 for SO2.

~~EPA Regulation of Greenhouse Gas Emissions from Existing Fossil Fuel-Fired EGUs~~2. On October 23, 2015, the EPA published a final rule in the Federal Register regulating greenhouse gas emissions from existing fossil fuel-fired electric generation units (EGUs) under Section 111(d) of the CAA (80 Fed. Reg. 64,662 (Oct. 23, 2015)). The rule (known as the Clean Power Plan or CPP) established emission guidelines for states to follow in developing plans to reduce greenhouse gas emissions from existing fossil fuel-fired EGUs. The CPP required that the states individually or collectively create systems that would reduce carbon emissions from any EGU located within their borders by 28% in 2025 and 32% in 2030 (compared with a 2005 baseline).

The EPA subsequently proposed to repeal the CPP and in August 2018 issued a proposed rule to replace the CPP, with the Affordable Clean Energy (ACE) Rule. In June 2019, the EPA issued a combined package that finalized the CPP repeal rule as well as the replacement rule, ACE. The ACE rule sets emissions guidelines for greenhouse gas emissions from existing EGUs based on a determination that efficiency heat rate improvements constitute the Best System of Emission Reduction (BSER). The EPA’s final rule also revises certain regulations to give the states greater flexibility on the content and timing of their state plans.

Based on the EPA’s final rules repealing and replacing the CPP, petitioners in the D.C. Circuit matter seeking review of CPP, including the Company, filed a motion to dismiss, which the court granted in September 2019.

Numerous petitions for review challenging the ACE Rule were filed in the D.C. Circuit and subsequently consolidated. In January 2021, a 3-judge panel of the D.C. Circuit vacated and remanded the ACE Rule to the EPA, including its repeal of the CPP and amendments to the implementing regulations that extended the compliance timeline.

On October 29, 2021, the Supreme Court granted certiorari in four matters seeking review of the D.C. Circuit’s opinion invalidating the repeal of the CPP. In granting certiorari, the Supreme Court consolidated the cases to consider the breadth of the EPA’s scope pursuant to 42 U.S.C. Section 7411(d) of the CAA, specifically, whether it is limited to issuing standards for ~~existing sources~~ achievable through demonstrated technology and methods, or if it may also issue industry wide systems (such as cap and trade) which effectively seek to shift energy generation. The Company will continue to monitor the consolidated matters.

Cross State Air Pollution Rule (CSAPR) and CSAPR Update Rule. In 2011, the EPA finalized the CSAPR, which requires the District of Columbia and 27 states from Texas eastward (not including the New England states or Delaware) to reduce power plant emissions that cross state lines and significantly contribute to ozone and/or fine particle pollution in other states. In 2016, the EPA published the final CSAPR Update Rule which imposed additional reductions in nitrogen oxides (NOx) beginning in 2017 in 22 states subject to CSAPR. This rule was subsequently remanded back to the EPA. Wisconsin v. EPA, 938 F.3d 303.

In ~~October 2020, the EPA proposed a rule to address a previous D.C. Circuit remand of the CSAPR Update Rule and in~~ April 2021, the EPA published a final rule in the Federal Register ~~which~~to address the D.C. Circuit remand. This rule imposed further reductions of NOx emissions in 12 states that were subject to the original 2016 ~~rule.~~rule, which was based on the 2008 ozone NAAQS.

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In the same rule, the EPA determined that 9 states did not significantly contribute to downwind nonattainment and/or maintenance issues and therefore did not require additional emission reductions. ~~In order to implement reductions in the 12 identified states, the~~The EPA subsequently issued Federal Implementation Plans (FIPs) to lower state ozone season NOx budgets in 2021 to 2024 ~~although limited emission trading can be used for compliance and states have~~in the ~~ability to replace federal plans with revised state plans that are no less stringent.~~affected states. A petition for review challenging the 2021 rule ~~has been~~was filed in the D.C. ~~Circuit,~~Circuit. Briefing is completed and oral arguments were held September 28, 2022, but this does not stay the effectiveness of the rule.

On April 6, 2022, the EPA proposed FIPs to address regional ozone transport for the 2015 ozone NAAQS. The proposed rule would result in new ozone season emission budgets for NOx in 25 states, including four Western states, and additionally contains provisions that would require daily “backstop” emission limits for coal-fired power plants over 100 megawatts. The proposed rule would also set first-time limits on certain industrial sources. The EPA estimates that by 2026 the compliance cost will be $1.1 billion. 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.

Mercury and Air Toxic Standards (MATS). The EPA published the final MATS rule in the Federal Register in 2012. The MATS rule revised the new source performance standards (NSPS) for NOx, SO2 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.

In 2020, the EPA issued a final rule reversing a prior finding and determined that it is not “appropriate and necessary” under the CAA to regulate HAP emissions from coal- and oil-fired power plants. This rule also finalized residual risk and technology review standards for the coal- and oil-fired ~~EGU~~electricity utility generating units source category. Both actions were challenged in the D.C. Circuit but this litigation was placed in abeyance. ~~In August 2020,~~On February 9, 2022 the EPA ~~sent~~proposed a rule to revoke the 2020 finding and to reaffirm the agency’s 2016 finding that it remains “appropriate and necessary” to regulate HAP emissions from coal- and oil-fired power plants under Clean Air Act section 112. In the same proposal, the EPA solicited comments on the performance and cost of new or improved technologies to control HAPs from these power plants as part of the agency’s review of related residual risk and technology review standards.

Clean Water Act (CWA). The CWA of 1972 directly impacts U.S. coal mining operations by requiring effluent limitations and treatment standards for wastewater discharge from mines through the National Pollutant Discharge Elimination System (NPDES). Regular monitoring, reporting and performance standards are requirements of NPDES permits that govern the discharge of water from mine-related point sources into receiving waters.

The U.S. Army Corps of Engineers (Corps) regulates certain activities affecting navigable waters and waters of the U.S., including wetlands. Section 404 of the CWA requires mining companies to obtain permits from the Corps to place material in or mine through jurisdictional waters of the U.S.

States are empowered to develop and apply water quality standards. These standards are subject to change and must be approved by the EPA. Discharges must either meet state water quality standards or be authorized through available regulatory processes such as alternate standards or variances. Standards vary from state to state. Additionally, through the CWA Section 401 certification program, state and tribal regulators have approval authority over federal permits or licenses that might result in a discharge to their waters. State and tribal regulators consider whether the activity will comply with their water quality standards and other applicable requirements in deciding whether or not to certify the activity. The EPA issued a final rule in 2020 that could limit state and tribal regulators’ authority by allowing the EPA to certify projects over state or tribal regulator objections in some circumstances. That rule was temporarily vacated by a district court, but a Supreme Court order on April 7, 2022, effectively reinstated the rule. The EPA issued another proposal in June 2022 that would supersede the 2020 rule and expand state and tribal regulators’ authority to review activities that require federal permits or licenses and to impose conditions they believe are necessary to ensure compliance with water quality requirements. Comments for this rule were due August 8, 2022 and final rule is expected in Spring 2023.

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National Environmental Policy Act (NEPA). NEPA, signed into law in 1970, requires federal agencies to review the environmental impacts of their decisions and issue either an environmental assessment or an environmental impact statement. Peabody must provide information to agencies when it proposes actions that will be under the authority of the federal government. The NEPA process involves public participation and can involve lengthy timeframes. The White House Council on Environmental Quality (CEQ) issued a final rule comprehensively updating and modernizing its longstanding NEPA regulations on July 16, 2020. That final rule sought to reduce unnecessary paperwork, burdens and delays, promote better coordination among agency decision makers, and clarify scope of NEPA reviews, among other things. States and environmental groups have filed several lawsuits challenging the final rule. On April 20, 2022, however, the CEQ published the final Phase 1 rule that partially amended the 2020 rule by restoring key provisions of the pre-2020 NEPA regulations. The CEQ plans to propose a Phase 2 rule in the near future that makes broader changes to the 2020 rule.

Black Lung Benefits Act Self-Insurance Requirements. The Department of Labor’s Office of Workers’ Compensation Programs (OWCP) is scheduled to propose a rule this year establishing requirements for Black Lung Benefits Act self-insurance. The Act requires each coal mine operator to secure the payment of its potential benefits liability by either qualifying as a self-insurer or by purchasing and maintaining a commercial insurance contract. The OWCP is responsible for authorizing coal mine operators to self-insure and for setting the appropriate security amounts. Appropriate security helps protect the Black Lung Disability Trust Fund, which pays benefits when operators fail to make payments due to bankruptcy or other reasons. As part of its ongoing efforts to reform the self-insurance program to ensure that operators are adequately securing their liabilities, OWCP proposes to update its regulations for authorizing operators to self-insure and for determining appropriate security amounts. On August 30, 2022, OWCP forwarded the draft rule to the Office of Management and Budget (OMB) for ~~review regarding reconsideration~~review.

SEC Climate-Related Disclosures. On March 21, 2022, the SEC proposed rules that would require public companies to disclose extensive climate-related information in certain SEC filings. Specifically, the proposed rules would add new Subpart 1500 to Regulation S-K and new Article 14 to Regulation S-X to require disclosure of climate-related risks that are reasonably likely to have a material impact on a public company’s business, results of operations, or financial condition; GHG emissions associated with a public company that includes, in many cases, an attestation report by a GHG emissions attestation provider; and climate-related financial metrics to be included in a company’s audited financial statements. The Company is currently assessing the potential impact of the ~~“appropriate~~proposed rules. The public comment period on the proposed rules has concluded and ~~necessary” finding~~final rules are expected late 2022 or early 2023.

Inflation Reduction Act of 2022. The Inflation Reduction Act of 2022 was signed into law on August 16, 2022. Among its many provisions are programs that provide grants and other forms of direct and indirect financial assistance for the deployment of zero emission technologies as well as ~~standards for coal-~~other actions that could affect energy markets and ~~oil-fired EGUs.~~

~~CWA Definition~~the future use of ~~“Waters~~coal. The legislation also implements a 15% minimum tax on book income of certain large corporations and a 1% excise tax on net stock repurchases. The Company is currently assessing the potential impacts of the ~~United States~~”. In January 2020 the EPA and the Army Corps of Engineers (Corps) finalized the Navigable Waters Protection Rule to revise the definition of “Waters of the United States” and thereby establish the scope of federal regulatory authority under the CWA. On August 30, 2021, a federal court in Arizona vacated the Navigable Waters Protection Rule, and on September 3, 2021, the EPA and the Corps announced that they had “halted implementation” of the rule nationwide and that they are interpreting “Waters of the United States” consistent with the pre-2015 regulatory framework. The agencies reaffirmed that they are moving forward on two rulemaking proceedings to formally repeal the Navigable Waters Protection Rule and then to build upon the pre-2015 regulatory framework.

~~Effluent Limitations Guidelines for the Steam Electric Power Generating Industry~~. On September 30, 2015, the EPA published a final rule setting new or additional requirements for various wastewater discharges from steam electric power plants. The rule set zero discharge requirements for some waste streams, as well as new, more stringent limits for arsenic, mercury, selenium and nitrogen applicable to certain other waste streams. On October 13, 2020, the EPA issued a final rule revising the technology-based effluent limitations guidelines and standards for the steam electric power generating point source category applicable to flue gas desulfurization wastewater and bottom ash transport water. However, on August 3, 2021, the EPA announced it is undertaking a supplemental rulemaking to “strengthen certain discharge limits” applicable to steam electric power plants. As finalized, the revised effluent limitations guidelines could significantly increase costs for many coal-fired steam electric power plants.legislation.

Regulatory Matters - Australia

Australian federal election. On May 21, 2022, Australia’s federal election resulted in the Labor Party replacing the former Coalition administration. The new Labor government plans several reforms to federal environmental and industrial relations laws that have the potential to negatively impact Australian mining ~~industry is regulated by~~operations; however, the majority of reforms are unlikely to be legislated until 2023. Proposed labor market reforms include legislation that would require contracted or labor hire workers undertaking the same roles as direct employees to be paid equal wages; reduced flexibility of employment; and changes to enterprise bargaining legislation that may increase the difficulty of reaching enterprise agreements.

The new Australian federal ~~state~~government has announced plans to legislate for a 43% reduction in Australia’s greenhouse gas emissions by 2030 and ~~local governments with respect~~ to ~~environmental issues such as land reclamation, water quality, air quality, dust control, noise, planning issues (such as approvals~~introduce changes by mid-2023 that will require heavy emitting companies producing more than 100,000 tonnes of carbon emissions annually to ~~expand existing mines or to develop new mines) and health and safety issues.~~accelerate their emissions reduction activities. The Australian federal government ~~retains control over~~has also committed to provide an official response to an independent review of Australia’s overarching environmental law, the ~~level~~Environment Protection and Biodiversity Conservation (EPBC) Act, by the end of ~~foreign investment~~2022, with the aim of developing strengthened environmental legislation in 2023.

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Sharma v Minister for the Environment. On March 15, 2022, the Full Court of the Federal Court of Australia overturned the decision in Sharma v Minister for the Environment [2021] FCA 560 (Sharma), a case which found in 2021 that the Federal Minister for the Environment had a duty to avoid causing personal injury or death to children in Australia as a result of carbon emissions when deciding an application to approve a coal mine expansion. In light of this decision, the Minister no longer must consider the effects of carbon emissions when assessing referrals under the Environment Protection and ~~export approvals. Industrial relations~~Biodiversity Conservation Act 1999. However, an application by Sharma for special leave to appeal to the High Court of Australia remains probable, and the duty could be reinstated.

Queensland royalties. On and from July 1, 2022, the Queensland Government introduced three new royalty tiers for coal produced and sold from the state. The new tier rates are ~~regulated under~~20% for the portion of prices above $175 Australian dollars per tonne; 30% for prices above $225 Australian dollars per tonne; and a 40% tier for when prices exceed $300 Australian dollars per tonne. Previously, the maximum royalty rate was 15% of the value of the coal sold above $150 Australian dollars per tonne. The change follows a three-year freeze on royalty rates for coal in the state. The Company is working with other coal producers to consider challenges to the implementation of the new royalty tiers.

Risks Related to Global Climate Change

Peabody recognizes that climate change is occurring and that human activity, including the use of fossil fuels, contributes to greenhouse gas (GHG) emissions. The Company’s largest contribution to GHG emissions occurs indirectly, through the coal used by its customers in the generation of electricity and the production of steel (Scope 3). To a lesser extent, the Company directly and indirectly contributes to GHG emissions from various aspects of its mining operations, including from the use of electrical power and combustible fuels, as well as from the fugitive methane emissions associated with coal mines and stockpiles (Scopes 1 and 2).

Peabody’s board of directors and management believe that coal is essential to affordable, reliable energy and will continue to play a significant role in the global energy mix for the foreseeable future. Peabody views technology as vital to advancing global climate change solutions, and the company supports advanced coal technologies to drive continuous improvement toward the ultimate goal of net-zero emissions from coal.

The board of directors has ultimate oversight for climate-related risk and opportunity assessments, and has delegated certain aspects of these assessments to subject matter committees of the board. In addition, the board and its committees are provided regular updates on major risks and changes, including climate-related matters. The senior management team champions the strategic objectives set forth by the board of directors and Peabody’s global workforce turns those objectives into meaningful actions.

Management believes that the Company’s external communications, including environmental regulatory filings and public notices, SEC filings, its annual Environmental, Social and Governance (ESG) Report, its website and various other stakeholder-focused publications provide a comprehensive picture of the Company’s material risks and progress. All such communications are subject to oversight and review protocols established by Peabody’s board of directors and executive leadership team.

The Company faces risks from both the global transition to a net-zero emissions economy and the potential physical impacts of climate change. Such risks may involve financial, policy, legal, technological, reputational and other impacts as the Company meets various mitigation and adaptation requirements.

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The transition to a net-zero emissions economy is driven by many factors, including, but not limited to, legislative and regulatory rulemaking processes, campaigns undertaken by non-governmental organizations to minimize or eliminate the use of coal as a source of electricity generation, and the ESG-related policies of financial institutions and other private companies. The Company has experienced, or may in the future experience, negative effects on its results of operations due to the following specific risks as a result of such factors:

•Reduced utilization or closure of existing coal-fired electricity generating plants;

•Electricity generators switching from coal to alternative fuels, when feasible;

•Increased costs associated with regulatory compliance;

•Unfavorable impact of regulatory compliance on supply and demand fundamentals, such as limitations on financing or construction of new coal-fueled power stations;

•Uncertainty and inconsistency in rulemaking processes related to periodic governmental administrative and policy changes;

•Unfavorable costs of capital and limited or no available access to financial markets and products due to the policies of financial institutions;

•Disruption to operations or markets due to anti-coal activism and litigation; and

•Reputational damage associated with involvement in GHG emissions.

With respect to the potential or actual physical impacts of climate change, the Company has identified the following specific risks:

•Disruption to water supplies vital to mining operations;

•Disruption to transportation and other supply chain activities;

•Damage to the Company’s, customers’ or suppliers’ plant and equipment, or third-party infrastructure, resulting from weather events or changes in environmental trends and conditions; and

•Electrical grid failures and power outages.

While the Company faces numerous risks associated with the transition to a net-zero emissions economy and the physical impacts of climate change, certain opportunities may also emerge, such as:

•Heightened emphasis among multiple stakeholders to develop high-efficiency, low-emissions (HELE) technologies and carbon capture, use and storage (CCUS) technologies;

•Increased steel demand related to construction and other infrastructure projects related to climate change concerns; and

•The relative expense and reliability of renewable energy sources compared to coal may encourage support for balanced-source energy policies and regulations.

Global climate issues continue to attract public and scientific attention. Numerous reports, such as the Fourth and the Fifth Assessment Report of the Intergovernmental Panel on Climate Change, have also engendered concern about the impacts of human activity, especially fossil fuel combustion, on global climate issues. In turn, increasing government attention is being paid to global climate issues and to GHG emissions, including emissions of carbon dioxide from coal combustion by power plants. There have been significant developments in federal and state laws. Australian state governments also require coal companies to post deposits or give other security against land which is being used for mining, with those deposits being incrementally returned or security released after satisfactory reclamation is progressively completed.

~~Safe Work Australia (SWA).~~ ~~As part of a broader review of workplace exposure standards, SWA is currently considering a proposal to reduce the time weighted average (TWA) Workplace Exposure Standard (WES) for carbon dioxide (CO~~2)legislation and regulation and international accords regarding climate change. Such developments are described within Part I, Item 1. “Business” in ~~Australian coal mines from 12,500 ppm to 5,000 ppm. Currently there is a separate TWA for CO~~2 ~~in coal mines however SWA proposes to remove this to align with a general industry standard. If implemented, the change has the potential to affect underground mines operating in CO~~2 ~~rich coal seams, including the primary coal seam of~~ the Company’s ~~Metropolitan Mine. Importantly, a minimum three-year transition period applies~~Annual Report on Form 10-K for ~~any change to standards.~~the year ended December 31, 2021.

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~~Environment Protection and Biodiversity Conservation Amendment (Standards and Assurance) Bill 2021.~~ On February 25, 2021 the Commonwealth Government introduced the Environment Protection and Biodiversity Conservation Amendment (Standards and Assurance) Bill 2021 into Parliament, which proposes amendments to the Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act) following the release of the Final Report of the Independent Review of the Act undertaken by Professor Graeme Samuel (the Samuel Review) that made 38 recommendations for short and long-term reforms, and ultimately calls for a complete overhaul of the existing legislative framework by 2022, to be undertaken in several tranches, with a strong focus on the setting of National Environmental Standards, assurance and compliance, data availability and management, and indigenous engagement. The bill responds to some of the recommendations for immediate reform made in the Samuel Review, and seeks to: establish a framework for the making, varying, revoking and application of National Environmental Standards; apply the National Environmental Standards to bilateral agreements with States and Territories; and establish an Environment Assurance Commissioner to monitor and audit bilateral agreements and other processes under the EPBC Act. The bill passed the Australian Parliament’s House of Representatives in June 2021 and is now under consideration by the Australian Senate.

~~Native Title and Cultural Heritage.~~ On February 3, 2021 the Native Title Act 1993 was amended, largely directed at improving the efficiency of the native title system for all parties. The amendments confirm the validity of most section 31 right to negotiate agreements which might be invalid because of non-execution by any of the persons comprising the registered native title claimant following the Full Federal Court's decision in McGlade v Registrar National Native Title Tribunal. Other significant amendments include that: during the right to negotiate process the parties to section 31 agreements are now required to notify the National Native Title Tribunal of the existence of any ancillary agreements; new section 47C allows historical extinguishment to be disregarded on park areas including extinguishment by public works; and new section 24MD(6B)(f) creates a new 8 month objection period for the creation of a right to mine for the purpose of an infrastructure facility associated with mining and to some compulsory acquisitions of native title.

~~Global Climate~~

In the U.S., Congress has considered legislation addressing global climate issues and greenhouse gas emissions, but to date, no legislation directly affecting fossil fuel-fired powerplants has been signed into law. Congress did include climate legislation, the American Innovation and Manufacturing Act of 2020, within a large appropriations bill for the 2021 fiscal year. This legislation was enacted in December 2020, and final regulations were promulgated in September 2021. The law requires the phasedown of the production and use of hydrofluorocarbons (HFCs) in the United States. While it is possible that the U.S. will adopt broader legislation in the future, the timing and specific requirements of any such legislation are uncertain. The U.S. Congress is considering several measures to address climate issues and greenhouse gas emissions as part of the U.S. budgetary process, including reconciliation legislation that could create financial incentives and penalties as part of a “clean electricity standard” applying to electric generation.

In the absence of new U.S. federal legislation, the EPA has taken steps to regulate greenhouse gas emissions pursuant to the CAA. In response to the U.S. Supreme Court ruling in Massachusetts v. EPA, 549 U.S. 497 (2007) the EPA commenced several rulemaking projects as described under “Regulatory Matters - U.S.” As described above, however, the EPA’s rules affecting existing fossil-fuel fired power plants (i.e. the ACE Rule and the EPA’s repeal of the CPP) were vacated and remanded back to the EPA by the D.C. Circuit. Greenhouse gas requirements for new, reconstructed and modified fossil fuel fired power plants remain in effect.

Several changes in the New Source Review (NSR) program, a permitting plan under the CAA for new source construction and major modifications, have also been issued through guidance and rulemaking as described under “Regulatory Matters – U.S.” in the Company’s Annual Report on Form 10-K. The NSR program provides for the pre-construction review of new, reconstructed and modified stationary sources and results in determinations concerning the emission control technology that must be installed and operated at a source. NSPS generally serve as a “floor” level of control for sources subject to NSR review; the final level of control is determined through the permitting process. In certain cases, performance standards or controls regarding greenhouse gas emissions may be required through the NSR process. Because NSR review is undertaken both pursuant to applicable regulations and guidance and performed on a “case-by-case” basis, requirements imposed through this permitting process are subject to variation.

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At the same time, a number of states in the U.S. have adopted programs to regulate greenhouse gas emissions. For example, 10 northeastern states (Connecticut, Delaware, Maine, Maryland, Massachusetts, New Hampshire, New Jersey, New York, Rhode Island and Vermont) entered into the Regional Greenhouse Gas Initiative (RGGI) in 2005, which is a mandatory cap-and-trade program to cap regional carbon dioxide emissions from power plants. Six mid-western states (Illinois, Iowa, Kansas, Michigan, Minnesota and Wisconsin) and one Canadian province have entered into the Midwestern Regional Greenhouse Gas Reduction Accord (MGGRA) to establish voluntary regional greenhouse gas reduction targets and develop a voluntary multi-sector cap-and-trade system to help meet the targets. It has been reported that, while the MGGRA has not been formally suspended, the participating states are no longer pursuing it. Seven western states (Arizona, California, Montana, New Mexico, Oregon, Utah and Washington) and four Canadian provinces entered into the Western Climate Initiative (WCI) in 2008 to establish a voluntary regional greenhouse gas reduction goal and develop market-based strategies to achieve emissions reductions. However, in November 2011, the WCI announced that six states had withdrawn from the WCI, leaving California and four Canadian provinces as the remaining members. Of those five jurisdictions, only California and Quebec have adopted greenhouse gas cap-and-trade regulations to date and both programs have begun operating. Many of the states and provinces that left WCI, RGGI and MGGRA, along with many that continue to participate, have joined the new North America 2050 initiative, which seeks to reduce greenhouse gas emissions and create economic opportunities in ways not limited to cap-and-trade programs. Separately, California has committed through Executive Order B-55-18 and SB 100 to 100 percent “clean energy” by 2045 and the state of Washington has passed legislation to commit to carbon neutrality by 2050.

Several other U.S. states have enacted legislation establishing greenhouse gas emissions reduction goals or requirements. In addition, several states have enacted legislation or have in effect regulations requiring electricity suppliers to use renewable energy sources to generate a certain percentage of power or that provide financial incentives to electricity suppliers for using renewable energy sources. Some states have initiated public utility proceedings that may establish values for carbon emissions.

Increasingly, both foreign and domestic banks, insurance companies and large investors are curtailing or ending their financial relationships with fossil fuel-related companies. This has had adverse impacts on the liquidity and operations of coal producers.

Peabody participated in the Department of Energy’s Voluntary Reporting of Greenhouse Gases Program until its suspension in May 2011, and Peabody regularly discloses in its annual Environmental, Social and Governance Report the quantity of emissions per ton of coal produced by the Company in the U.S. The vast majority of the Company’s emissions are generated by the operation of heavy machinery to extract and transport material at its mines and fugitive emissions from the extraction of coal.

The Kyoto Protocol, adopted in December 1997 by the signatories to the 1992 United Nations Framework Convention on Climate Change (UNFCCC), established a binding set of greenhouse gas emission targets for developed nations. The U.S. signed the Kyoto Protocol but it has never been ratified by the U.S. Senate. Australia ratified the Kyoto Protocol in December 2007 and became a full member in March 2008. There were discussions to develop a treaty to replace the Kyoto Protocol after the expiration of its commitment period in 2012, including at the UNFCCC conferences in Cancun (2010), Durban (2011), Doha (2012) and Paris (2015). At the Durban conference, an ad hoc working group was established to develop a protocol, another legal instrument or an agreed outcome with legal force under the UNFCCC, applicable to all parties. At the Doha meeting, an amendment to the Kyoto Protocol was adopted, which included new commitments for certain parties in a second commitment period, from 2013 to 2020. In December 2012, Australia signed on to the second commitment period. During the UNFCCC conference in Paris, France in late 2015, an agreement was adopted calling for voluntary emissions reductions contributions after the second commitment period ends in 2020 (the Paris Agreement). The agreement was entered into force on November 4, 2016 after ratification and execution by more than 55 countries, including Australia, that account for at least 55% of global greenhouse gas emissions.

In January 2021, the U.S. reentered the Paris Agreement by accepting the agreement and all of its articles and clauses, after having announced its withdrawal from the agreement in November 2019. In April 2021, the U.S. announced its own Nationally Determined Contribution (NDC) with respect to the Paris Agreement. The NDC is voluntary and would aim to cut carbon dioxide output by 50% to 52% compared with 2005 levels by 2030. Recently, the U.S. has announced the goal of a completely emissions-free power grid by 2035, but has not provided additional, more specific information with regard to how the goal will be achieved. The Company anticipates a series of executive actions and/or orders from the current presidential administration aimed at curbing emission levels as well as associated rulemaking using the CAA and potentially other statutory and/or spending authorities.

~~Table of Contents~~

In October 2017, the Australian Federal Government released a plan aimed at delivering an affordable and reliable energy system that meets Australia’s international commitments to emissions reduction. The plan was referred to as the National Energy Guarantee (NEG) and was aimed at changing the National Electricity Market and associated legislative framework. The NEG was abandoned by the Australian government in September 2018. Following the outcome of the federal election in May 2019, the federal government confirmed it will not revive the former NEG policy. Instead, the government will pursue a new energy and climate change policy, which includes a $2 billion Australian dollars investment in projects to bring down Australia's greenhouse gas emissions. The Climate Solutions Fund is an extension of the former Emissions Reduction Fund. The government has confirmed that it remains committed to meeting Australia’s Paris Agreement targets but has not formally committed to net zero emissions by 2050 with the focus of energy policy on the use of technology to accelerate the development and commercialization of low and zero emissions technologies and driving down electricity prices.

The enactment of future laws or the passage of regulations regarding emissions from the use of coal by the U.S., some of its states or other countries, or other actions to limit such emissions, could result in electricity generators switching from coal to other fuel sources. Further, policies limiting available financing for the development of new coal-fueled power stations could adversely impact the global demand for coal in the future. The potential financial impact on ~~the Company~~Peabody of such future laws, regulations or other policies will depend upon the degree to which any such laws or regulations force electricity generators to diminish their reliance on coal as a fuel source. That, in turn, will depend on a number of factors, including the specific requirements imposed by any such laws, regulations or other policies, the time periods over which those laws, regulations or other policies would be phased in, the state of development and deployment of ~~carbon capture, utilization and storage (CCUS)~~CCUS technologies as well as acceptance of CCUS technologies to meet regulations and the alternative uses for coal. Higher-efficiency coal-fired power plants may also be an option for meeting laws or regulations related to emissions from coal use. Several countries, including major coal users such as China, India and Japan, included using higher-efficiency coal-fueled power plants in their plans under the Paris Agreement. The Company believes HELE and CCUS technologies should be part of the solution to achieve substantial reductions in GHG emissions and should be broadly supported and encouraged, including through eligibility for public funding from national and international sources. In addition, CCUS merits targeted deployment incentives, like those provided to other low-emission sources of energy.

From time to time, ~~Peabody attempts~~the Company’s board of directors and management attempt to analyze the potential impact on the Company of as-yet-unadopted, potential laws, regulations and policies. Such analyses require ~~that Peabody make~~ significant assumptions as to the specific provisions of such potential laws, regulations and policies which sometimes show that if implemented in the manner assumed by the analyses, the potential laws, regulations and policies could result in material adverse impacts on ~~its~~the Company’s operations, financial condition or cash ~~flow. The Company does not believe that such~~flows. Such analyses cannot be relied upon to reasonably predict the quantitative impact that future laws, regulations or other policies may have on ~~its~~the Company’s results of operations, financial condition or cash flows.

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, capital and operating lease payments, postretirement plans, take-or-pay obligations, post-mining reclamation obligations, collateral and margining requirements, and selling and administrative expenses. The Company has also used cash for ~~dividends, share repurchases and~~ early debt ~~retirements.~~retirements, dividends, and share repurchases.

Any future determinations to return capital to stockholders, such as dividends or share repurchases will depend on a variety of factors, including the restrictions set forth under the Company’s debt and surety agreements, its 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. The Company has presently suspended the payment of dividends and share repurchases, as discussed in Part II, Item 2. “Unregistered Sales of Equity Securities and Use of Proceeds.”

Liquidity

As of September 30, ~~2021,~~2022, the Company’s cash balances totaled ~~$587.0~~$1,354.5 million, including approximately ~~$265~~$742 million held by U.S. subsidiaries, ~~$294~~$578 million held by Australian subsidiaries, and the remainder held by other foreign subsidiaries in accounts predominantly domiciled in the U.S. The Australian subsidiaries that conduct the operations of the Wilpinjong Mine held cash of approximately ~~$145~~$203 million at September 30, ~~2021.~~2022. 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 nine months ended September 30, 2022, the Company repatriated approximately $1.1 billion. 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.

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The Company’s available liquidity ~~declined~~increased from ~~$728.7~~$995.9 million as of December 31, ~~2020~~2021 to ~~$615.4~~$1,369.2 million as of September 30, ~~2021.~~2022. Available liquidity was comprised of the following:

September 30, 2021 December 31, 2020
(Dollars in millions)
Cash and cash equivalents $ 587.0 $ 709.2
Credit facility availability 15.8 0.2
Accounts receivable securitization program availability 12.6 19.3
Total liquidity $ 615.4 $ 728.7

~~Indebtedness~~

~~The Company’s total funded indebtedness (Indebtedness) as of September 30, 2021 and December 31, 2020 is presented in the table below.~~

~~The Company’s Indebtedness was significantly impacted subsequent to December 31, 2020 as a result of various agreements and transactions described below.~~

~~Refinancing and Related Transactions~~


	September 30, 2022		December 31, 2021
	(Dollars in millions)
Cash and cash equivalents	$	1,354.5	$	954.3
Credit facility availability	3.8		15.3
Accounts receivable securitization program availability	10.9		26.3
Total liquidity	$	1,369.2	$	995.9

During the ~~fourth quarter~~nine months ended September 30, 2022, the Company executed an amendment to its credit facility and mandatorily reduced its capacity by approximately $22 million to make allowable certain previously restricted payments for joint venture investments. The amendment creates an investment basket which allows payments of ~~2020~~$30.0 million per year specifically limited to investment in renewable energy-related projects. Unused portions of the basket carryover from year-to-year, and the total amount of investment will further reduce the credit facility capacity by a like amount, or a minimum of $10.0 million per year, through the maturity of the credit facility. The Company expects to utilize its collateralized letter of credit agreement, described below, to offset future required credit facility capacity reductions. The Company has no contractual commitment for renewable energy-related project investment.

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 2022, the Company’s margin requirements have been driven primarily by coal derivative contracts entered into in the first ~~quarter~~half of 2021 related to 1.9 million metric tons of production at the Wambo Underground Mine in the Company’s Seaborne Thermal Mining segment. Based on planned production, the contracts were expected to settle at a rate of 1.2 million metric tons in 2022 and 0.7 million metric tons in 2023.

High demand and tight supply for coal globally during 2022 has resulted in a substantial rise in seaborne thermal coal prices, which has been amplified by the Russian-Ukrainian conflict resulting in unprecedented upward volatility in Newcastle coal pricing since late February. The Newcastle financial price has reached over $450 per metric ton during 2022, compared to approximately $169 per metric ton on December 31, 2021. As a result, the Company’s total initial and variation margin requirements reached approximately $750 million during March 2022. Margin is returned to the Company upon reductions in the underlying market coal price or, absent such reductions, cash is recovered as the Company delivers coal into the market at spot prices.

In order to meet its near-term liquidity requirements, particularly with respect to cash margin, the Company entered into a ~~series~~$150 million unsecured revolving credit facility in March 2022. Concurrently with this agreement, the Company entered into an agreement for at-the-market equity offerings of ~~interrelated agreements with its surety bond providers,~~up to $225.0 million of the Company’s common stock. During the three months ended March 31, 2022, the Company borrowed and repaid $225.0 million under the revolving ~~lenders under~~credit facility using net proceeds of $222.0 million from at-the-market issuances of 10.1 million shares of common stock and available cash. The Company made no additional borrowings and terminated the facility prior to its ~~credit agreement and certain holders of its senior secured notes~~scheduled 2025 maturity, on August 4, 2022.

To reduce exposure to ~~extend a significant portion of its near-term debt maturities to December 2024 and to stabilize collateral~~additional margin requirements, ~~for its existing surety bond portfolio. Such agreements and related activities are described below.~~

~~Organizational Realignment~~

~~In July and August 2020,~~during the nine months ended September 30, 2022, the Company ~~effected certain changes~~converted 0.8 million metric tons of financial hedges into fixed price physical sales through the first half of 2023. As of September 30, 2022, 0.9 million metric tons remain outstanding with 0.3 million metric tons projected to ~~its corporate structure in contemplation~~settle over the remainder of ~~a debt-for-debt exchange, which included, among other steps,~~2022.

On September 30, 2022, the ~~formation~~Company had $465.9 million of ~~certain wholly-owned subsidiaries (the Co-Issuers). In connection with~~margin posted. On October 31, 2022, the ~~change in structure,~~Company had $361.7 million of margin posted. For additional information regarding the Company’s ~~subsidiary which owns~~coal derivative contracts, refer to Part I, Item 3. “Quantitative and ~~operates its Wilpinjong Mine in Australia became a subsidiary~~Qualitative Disclosures About Market Risk” of the Co-Issuers. The Co-Issuers and the Wilpinjong subsidiary were designated as unrestricted subsidiaries under the Company’s credit agreement (Credit Agreement) and its senior notes’ indenture (the Existing Indenture). In connection with these actions, the Company contributed $100.0 million to the Co-Issuers to provide the Wilpinjong Mine with operating liquidity and address its near-term capital needs.this Quarterly Report.

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~~Surety Agreement~~Collateral Requirements

In November 2020, the Company entered into ~~a surety transaction support~~an agreement ~~(Surety Agreement)~~ with the providers ~~of 99%~~ of its surety bond portfolio ~~(Participating Sureties)~~ to resolve previous collateral ~~demands made by the Participating Sureties.~~demands. In accordance with the ~~Surety Agreement,~~agreement, the Company initially provided $75.0 million of collateral, in the form of letters of credit.

~~Upon completion of the Refinancing Transactions, as defined below, other provisions of the Surety Agreement became effective. In particular, the~~ The Company subsequently granted second liens on $200.0 million of certain mining equipment and ~~will~~is further required to post an additional $25.0 million of collateral per year from 2021 through 2024 for the benefit of the ~~Participating Sureties.~~surety providers. The collateral postings ~~may also~~ further increase to the extent the Company generates more than $100.0 million of free cash flow (as defined in the ~~Surety Agreement)~~surety agreement) in any twelve-month period or has cumulative asset sales in excess of $10.0 million, as of the last quarter end during the term of the agreement. ~~Further,~~Based upon the ~~Participating Sureties have agreed to a standstill through~~Company’s free cash flow since entering into the ~~earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025), during which time, the Participating Sureties will not demand any~~surety agreement, additional collateral ~~draw on~~of $38.7 million was posted during the nine months ended September 30, 2022 and $57.4 million was posted subsequent to September 30, 2022, in the form of cash-collateralized letters of credit. The Company is unable to accurately estimate future additional collateral postings due to the sensitivity of free cash flow to external market factors such as coal pricing.

Collateralized Letter of Credit Agreement

In February 2022, the Company entered into a new agreement, which provides up to $250.0 million of capacity for irrevocable standby letters of credit, ~~posted for the benefit of themselves or cancel any existing surety bond.~~expected to primarily support reclamation bonding requirements. The ~~Company will not pay dividends or make share repurchases during the standstill period, unless otherwise agreed between parties.~~

~~Refinancing Transactions~~

~~On January 29, 2021 (the Settlement Date),~~agreement requires the Company ~~completed~~to provide cash collateral at a ~~series~~level of transactions (collectively, the Refinancing Transactions) to, among other things, provide it with maturity extensions and covenant relief, while allowing it to maintain near-term operating liquidity and financial flexibility. The Refinancing Transactions included a senior notes exchange and related consent solicitation, a revolving credit facility exchange and various amendments to its existing debt agreements, as summarized below.

~~Exchange Offer~~

~~On the Settlement Date, the Company settled an exchange offer (Exchange Offer) pursuant to which $398.7 million aggregate principal amount~~103% of its 6.000% Senior Secured Notes due March 2022 (2022 Notes) were validly tendered, accepted by the Company and exchanged for aggregate consideration consisting of (a) $193.9 million aggregate principal amount of new 10.000% Senior Secured Notes due 2024 issued by the Co-Issuers (Co-Issuer Notes), (b) $195.1 million aggregate principal amount of new 8.500% Senior Secured Notes due 2024 issued by Peabody (Peabody Notes), and (c) a cash payment of approximately $9.4 million. In connection with the settlement of the Exchange Offer, the Company also paid early tender premiums totaling $4.0 million in cash. Refer to Note 11. “Long-term Debt” for additional information associated with the Co-Issuer Notes and the Peabody Notes.

As required under the Exchange Offer, the Company purchased $22.4 million of the Peabody Notes at 80% of their accreted value, plus accrued and unpaid interest, during the first quarter of 2021 and recognized a related net gain on extinguishment of $3.5 million.

~~Consent Solicitation~~

Concurrently with the Exchange Offer, the Company solicited consents from holders of the 2022 Notes to certain proposed amendments to the Existing Indenture to (i) eliminate substantially all of the restrictive covenants, certain events of default applicable to the 2022 Notes and certain other provisions contained in the Existing Indenture and (ii) release the collateral securing the 2022 Notes and eliminate certain other related provisions contained in the Existing Indenture. The Company received the requisite consents from holders of the 2022 Notes and entered into a supplemental indenture to the Existing Indenture, which became operative on January 29, 2021.

~~Revolver Transactions~~

~~In connection with the Refinancing Transactions, the Company restructured the revolving loans under the Credit Agreement by (i) making a pay down of revolving loans thereunder in~~ the aggregate amount of ~~$10.0~~letters of credit outstanding under the arrangement (limited to $5.0 million ~~(ii)~~total excess collateralization.) Outstanding letters of credit bear a fixed fee in the ~~Co-Issuers incurring $206.0~~amount of 0.75% per annum. The Company receives a deposit rate of 2.24% per annum on the amount of cash collateral posted in support of letters of credit, with the rate subject to variation over time. The agreement has an initial expiration date of December 31, 2025. At September 30, 2022, letters of credit of $43.2 million were outstanding under the agreement, which were collateralized by cash of ~~term loans under a credit agreement, dated~~$44.5 million.

Capital Expenditures

The Company increased its targeted capital expenditures for 2022 from approximately $190 million to $210 million, which includes an increase of major project and growth capital expenditures from approximately $80 million to $100 million.

Indebtedness

The Company’s total indebtedness as of ~~the Settlement Date (Co-Issuer Term Loans, Co-Issuer Term Loan Agreement), (iii) Peabody entering into a letter of credit facility (the Company LC Agreement),~~September 30, 2022 and ~~(iv) amending the Credit Agreement (collectively, the Revolver Transactions).~~

~~The Co-Issuer Term Loans mature on~~ December 31, ~~2024 and bear interest at a rate of 10.00% per annum.~~2021 is presented in the table below.


Debt Instrument (defined below, as applicable)	September 30, 2022		December 31, 2021
	(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	—	$	23.1
8.500% Senior Secured Notes due December 2024 (2024 Peabody Notes)	—		62.6
10.000% Senior Secured Notes due December 2024 (2024 Co-Issuer Notes)	81.6		193.9
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	114.6		206.0
6.375% Senior Secured Notes due March 2025 (2025 Notes)	66.2		334.9
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	282.6		322.8
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	320.0		—


Finance lease obligations	25.7		29.3
Less: Debt issuance costs	(21.5)		(34.8)
	869.2		1,137.8
Less: Current portion of long-term debt	546.9		59.6
Long-term debt	$	322.3	$	1,078.2

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OnThe Company’s indebtedness requires estimated contractual principal and interest payments, assuming interest rates in effect at September 30, 2022, of approximately $20 million during the ~~Settlement Date,~~three months ending December 31, 2022, and approximately $65 million in 2023, $260 million in 2024, $360 million in 2025, and $355 million thereafter. However, certain pending transactions, as further described below, and the Company’s positive intent and ability to repurchase additional debt principal in advance of contractual maturity dates could alter the timing and amount of principal and interest payments. In the accompanying condensed consolidated balance sheets, the Company ~~entered into~~classified all debt, with the exception of the 2028 Convertible Notes and finance lease obligations, as current obligations at September 30, 2022.

Cash payments for interest related to the Company’s indebtedness and financial assurance instruments amounted to $26.4 million and $40.0 million during the three months ended September 30, 2022 and 2021, respectively, and $104.2 million and $144.3 million during the nine months ended September 30, 2022 and 2021, respectively.

2021 Financing Activity and Subsequent Debt Repurchases

During the first quarter of 2021, the Company ~~LC Agreement~~completed a series of transactions to provide the Company with maturity extensions and covenant relief, while allowing it to maintain near-term operating liquidity. These transactions included a senior notes exchange, a revolving credit facility exchange, various amendments to the Company’s existing debt agreements, and a support agreement with the ~~revolving lenders party~~Company’s surety bond providers.

Subsequent to these transactions, the ~~Credit Agreement,~~Company completed additional financing transactions during 2021 which included the implementation of an at-the-market equity offering program pursuant to which the Company ~~obtained a $324.0~~sold approximately 24.8 million shares of common stock for net cash proceeds of $269.8 million, the retirement of $270.9 million principal amount of existing debt through various open market purchases at an aggregate cost of $232.4 million, and the issuance of an aggregate 10.0 million shares of common stock in exchange for an additional $106.1 million principal amount of existing debt through multiple bilateral transactions with debt holders.

In the event of open market purchases of its debt, the terms of the 2024 Peabody Notes - now redeemed as described below - required, and the letter of credit facility ~~under which its existing letters of credit under the Credit Agreement were deemed to be issued. The commitments under~~entered into by the Company LC Agreement mature on December 31, 2024. Undrawn letters of credit under the Company LC Agreement bear interest at 6.00% per annum and unused commitments are subject to a 0.50% per annum commitment fee.

Inin connection with the ~~Revolver Transactions, the Company amended the Credit Agreement to make certain changes in consideration of the Company~~2021 financing activity (Company LC Agreement. After giving effect to the Revolver Transactions, there remain no revolving commitments or revolving loans under the Credit Agreement and the first lien net leverage ratio covenant was eliminated. The Company LC AgreementAgreement) requires that the Company’s restricted subsidiaries maintain minimum aggregate liquidity of $125.0 million at the end of each quarter through December 31, 2024. As such, liquidity attributable to the Co-Issuers, its subsidiaries and other unrestricted subsidiaries is excluded from the calculation. Liquidity calculated in this manner amounted to $452.2 million at September 30, 2021.

~~The indenture which governs the Peabody Notes and the Company LC Agreement allow~~ the Company to make ~~open market~~repurchase offers to those debt ~~repurchases, subject~~and lien holders. In general, the repurchase offers equate to ~~certain limitations, including, but not limited to: (i)~~25% of the Company’s unrestricted subsidiaries’ liquidity must be greater than or equal to $200.0 million after giving effect to such repurchases and (ii) for every $4 of principal repurchased in any fiscal quarter, the Company must make an offer on a pro rata basis to purchase $1 of principal amount of ~~debt from holders of the Peabody Notes and the~~ priority lien ~~obligations under~~debt repurchased in the ~~Company LC Agreement within 30 days of the end of such fiscal~~preceding quarter at a price equal to the weighted average repurchase price paid over that ~~quarter (Mandatory Repurchase Offer).~~

~~Other Debt Financing~~

quarter. The Refinancing Transactions did not significantly impact the Company’s existing senior secured term loan under the Credit Facility (Senior Secured Term Loan), or its $500.0 million of 6.375% senior secured notes due March 2025 (2025 Notes), but these debt instruments were impacted by subsequent financing transactions described below. The term loan requires quarterly principal payments of $1.0 million and periodic interest payments, currently at LIBOR plus 2.75%, through December 2024 with the remaining balance due in March 2025. The senior secured notes require semi-annual interest payments each March 31 and September 30 until maturity.

The Company’s debt agreements impose various restrictions and limits on certain categories of payments that the Company may make, such as those for dividends, investments, and stock repurchases. The Company is also subject to customary affirmative and negative covenants. The Company was compliant with all covenants under its debt agreements including the minimum liquidity covenant under the Company LC Agreement at September 30, 2021.

~~Subsequent Financing Transactions~~

~~Subsequent to the Refinancing Transactions, the Company completed a series of financing transactions intended to improve its capital structure.~~

~~Through September 30, 2021, the Company retired $40.1 million of Peabody Notes, $19.7 million of 2025 Notes and $56.7 million of its Senior Secured Term Loan primarily through various~~ open market ~~purchases at an aggregate cost of $85.9 million. During the nine months ended September 30, 2021, the Company recorded net gains on early~~ debt extinguishment of $26.9 million related to these retirements. Subsequent to September 30, 2021, the Company retired an additional $5.0 million of its Senior Secured Term Loan through similar open market purchases for an aggregate cost of $3.3 million.

~~Through September 30, 2021, the Company also~~repurchases completed multiple bilateral transactions with holders of the 2022 Notes, the 2025 Notes and the Peabody Notes in which the Company issued an aggregate 6.7 million shares of its common stock in exchange for $37.3 million aggregate principal amount of the 2022 Notes, $17.9 million aggregate principal amount of the 2025 Notes and $5.5 million aggregate principal amount of the Peabody Notes. Between October 1, 2021 and November 2, 2021, the Company issued an additional 1.9 million shares of its common stock in exchange for $31.0 million aggregate principal amount of a combination of Peabody Notes and 2025 Notes.

~~Table of Contents~~

~~As a result of the Company’s open market purchases of its debt~~ during the three months ended ~~September 30,~~December 31, 2021 ~~on October 22, 2021, the Company announced~~necessitated a ~~Mandatory Repurchase Offer~~mandatory repurchase offer of up to ~~$15.8~~$38.6 million of 2024 Peabody Notes, at ~~73.590%~~94.940% of their aggregate accreted value, plus accrued and unpaid interest, and a concurrent repurchase offer of priority lien obligations under the Company LC Agreement. The ~~offers~~offer resulted in the valid tender and purchase of $0.1 million aggregate accreted value of 2024 Peabody Notes and $30.0 million aggregate principal and commitment amounts under the Company LC Agreement during the three months ended March 31, 2022. The Company’s purchase of the principal and commitment amounts under the Company LC Agreement was effected by the posting of $28.5 million of collateral with the administrative agent and did not reduce the availability under the facility. During the three months ended September 30, 2022, the Company repurchased $48.8 million aggregate principal amount of its Senior Secured Term Loan and 2025 Notes for $46.6 million in various open market transactions. As a result of these repurchases, the Company made a mandatory offer to repurchase $12.2 million of priority lien obligations under the Company LC Agreement at 95.57% on October 17, 2022. The offer will expire on November ~~22,~~16, 2022.

The 2024 Co-Issuer Notes and the Co-Issuer Term Loans are also subject to mandatory prepayment offers at the end of each six-month period, beginning with June 30, 2021, ~~unless extended~~whereby the Excess Cash Flow (as defined in the 2024 Co-Issuer Notes indenture) generated by the ~~Company.~~

~~Considering~~Wilpinjong Mine during each such period will be applied to the ~~Refinancing Transactions~~principal of such notes and loans on a pro rata basis, provided that the liquidity attributable to the Wilpinjong Mine would not fall below $60.0 million. Such prepayments may be accepted or declined at the option of the debt holders. Based upon the Wilpinjong Mine’s results for the six-month period ended December 31, 2021, a required offer to prepay $105.6 million of total principal resulted in the prepayment of $17.2 million of Co-Issuer Term Loans principal, $0.3 million of 2024 Co-Issuer Notes principal, and a related loss on early debt extinguishment of $0.5 million during the three months ended March 31, 2022. Based upon the Wilpinjong Mine’s results for the six-month period ended June 30, 2022, the Company was required to offer to prepay $65.1 million of total principal subsequent to June 30, 2022. The holders of the Co-Issuer Term Loans unanimously declined their $37.9 million pro rata portion of the offer and the ~~subsequent financing transactions~~holders of the 2024 Co-Issuer Notes tendered for prepayment $18.2 millon principal amount of their $27.2 million pro rata portion of the offer. The Company completed the prepayment during the three months ended September 30, 2022.

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The indenture which governs the 2024 Co-Issuer Notes requires that, within 30 business days following a repurchase of the Co-Issuer Term Loans such as that undertaken through the auction processes described above, the Company ~~expects~~must also offer to ~~incur approximately $190~~repurchase an equivalent principal amount of the 2024 Co-Issuer Notes at the equivalent purchase price. Further, the credit agreement which governs the Co-Issuer Term Loans requires parity between the holders of Co-Issuer Term Loans and holders of the 2024 Co-Issuer Notes with respect to repurchase offers. As a result of the modified Dutch auction process completed during the three months ended June 30, 2022, the required equivalent offer to purchase $50.0 million aggregate principal amount of 2024 Co-Issuer Notes was made by the Company on May 26, 2022 and was subsequently increased to $93.9 million, at the Company’s discretion. The offer was fully tendered and the Company completed the repurchase on July 25, 2022 for $97.5 million. The discretionary increase to the 2024 Co-Issuer Notes repurchase offer compelled the Company to offer to repurchase an additional $43.9 million principal amount of Co-Issuer Term Loans at 103.91% which resulted in the valid tender and purchase of $3.8 million principal for $4.0 million during the three months ended September 30, 2022.

Retirement of 2022 Notes

On March 31, 2022, the Company retired the remaining principal balance of 2022 Notes upon maturity for $23.1 million.

3.250% Convertible Senior Notes due 2028

The Company used the proceeds of the offering of the 2028 Convertible Notes to redeem the remaining $62.6 million of ~~interest expense, including~~its outstanding 2024 Peabody Notes and, together with available cash, approximately ~~$45~~$257.4 million of ~~non-cash interest expense,~~its outstanding 2025 Notes, and to pay related premiums, fees and expenses relating to the offering of the 2028 Convertible Notes and the 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 ~~year~~three months ended ~~December~~March 31, ~~2021.~~2022.

~~Refer to~~The 2028 Convertible Notes will mature on March 1, 2028, unless earlier converted, redeemed or repurchased in accordance with their terms, as described in Note ~~11.~~9. “Long-term Debt” of the accompanying unaudited condensed consolidated financial ~~statements for additional information related~~statements. 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.

Covenant Compliance

The Company was compliant with all relevant covenants under its debt agreements at September 30, 2022, including the minimum aggregate liquidity requirement under the Company LC Agreement which requires the Company’s restricted subsidiaries to maintain minimum aggregate liquidity of $125.0 million at the ~~subsequent financing transactions described above.~~end of each quarter through December 31, 2024. The Company’s restricted subsidiaries’ relevant liquidity amounted to $1,160.9 million at September 30, 2022.

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Accounts Receivable Securitization Program

As described in Note ~~16.~~12. “Financial Instruments and Other Guarantees” of the accompanying unaudited condensed consolidated financial statements, the Company entered into an accounts receivable securitization program during ~~2017 which currently matures~~2017. The securitization program was amended in ~~2022. The Company is in discussions~~January 2022 to ~~renew~~extend its maturity to January 2025 and reduce the ~~facility prior to maturity. The program provides for up to~~available funding capacity from $250.0 million ~~in funding,~~to $175.0 million, which better aligns with the current average borrowing base. 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. At September 30, ~~2021,~~2022, the Company hadhad no outstanding borrowings and ~~$133.6~~$164.1 million of letters of credit ~~issued~~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~~securitization program at September 30, ~~2021.~~

~~Capital Requirements~~

For 2021, the Company is targeting capital expenditures of approximately $200 million, which includes approximately $100 million for ongoing extension projects primarily related to its Seaborne Thermal Mining segment. The Company has no substantial future payment requirements under U.S. federal coal reserve leases.

~~Contractual Obligations~~

There were no material changes to the Company’s contractual obligations from the information previously provided in Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.2022.

Cash Flows and Free Cash Flow

The following table summarizes the Company’s cash flows for the nine months ended September 30, ~~2021~~2022 and ~~2020,~~2021, as reported in the accompanying unaudited condensed consolidated financial statements. 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.

Nine Months Ended September 30,
2021 2020
(Dollars in millions)
Net cash used in operating activities $ (18.4) $ (32.1)
Net cash used in investing activities (119.7) (159.4)
Net cash provided by financing activities 15.9 273.9
Net change in cash, cash equivalents and restricted cash (122.2) 82.4
Cash, cash equivalents and restricted cash at beginning of period 709.2 732.2
Cash, cash equivalents and restricted cash at end of period $ 587.0 $ 814.6
Net cash used in operating activities $ (18.4) $ (32.1)
Net cash used in investing activities (119.7) (159.4)
Free Cash Flow $ (138.1) $ (191.5)

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	Nine Months Ended September 30,
	2022		2021
	(Dollars in millions)
Net cash provided by (used in) operating activities	$	504.1	$	(18.4)
Net cash provided by (used in) investing activities	61.1		(119.7)
Net cash (used in) provided by financing activities	(120.5)		15.9
Net change in cash, cash equivalents and restricted cash	444.7		(122.2)
Cash, cash equivalents and restricted cash at beginning of period	954.3		709.2
Cash, cash equivalents and restricted cash at end of period	$	1,399.0	$	587.0

Net cash provided by (used in) operating activities	$	504.1	$	(18.4)
Net cash provided by (used in) investing activities	61.1		(119.7)

Free Cash Flow	$	565.2	$	(138.1)

Operating Activities. The ~~decrease~~increase in net cash ~~used in~~provided by operating activities for the nine months ended September 30, ~~2021~~2022 compared to the same period in the prior year was driven by a year-over-year increase in operating cash flow, primarily from ~~the~~ Company’s mining operations ($~~237.7~~858.3 million), partially offset by ~~increased~~ cash utilized to satisfy the unfavorable margin requirements associated with derivative financial instruments ($~~224.0~~335.8 million).

Investing Activities. The ~~decrease~~increase in net cash ~~used in~~provided by investing activities for the nine months ended September 30, ~~2021~~2022 compared to the same period in the prior year was driven by higher cash receipts from Middlemount ($146.5 million), increased proceeds from disposal of assets ($17.9 million) and lower capital expenditures ~~($19.9 million)~~ and ~~lower advances to related parties and joint ventures, on a net basis~~payments of capital accruals ($~~13.4~~14.1 million).

Financing Activities. The ~~decrease~~increase in net cash ~~provided by~~used in financing activities for the nine months ended September 30, ~~2021~~2022 compared to the same period in the prior year was driven by ~~$360.0 million of revolving loan and securitization borrowings in the prior year,~~ higher repayments of debt principal ($~~52.6~~712.7 million) and ~~payments for deferred financing costs~~higher distributions to non-controlling interests ($~~22.5~~13.6 million) ~~in the current year,~~, partially offset by ~~$177.2 million~~higher cash proceeds from ~~the issuance of~~long-term debt and common stock ~~in the current year.~~issuances ($545.0 million and $44.8 million, respectively).

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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. At September 30, ~~2021,~~2022, such instruments included ~~$1,462.4~~$1,380.5 million of surety bonds and ~~$443.2~~$505.4 million of letters of credit. Such financial instruments provide support for its 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 its condensed consolidated balance sheets.

As of September 30, ~~2021,~~2022, the Company was party to financial instruments with off-balance-sheet risk in support of the following obligations:


		Reclamation		Health and welfare (1)		Contract performance (2)		Leased property and equipment		Other (3)		Total			Reclamation		Health and welfare (1)		Contract performance (2)		Leased property and equipment		Other (3)		Total
		(Dollars in millions)													(Dollars in millions)
Surety bonds and bank guarantees	Surety bonds and bank guarantees	$	1,293.4	$	42.1	$	79.6	$	30.9	$	16.4	$	1,462.4	Surety bonds and bank guarantees	$	1,234.6	$	40.5	$	55.9	$	33.3	$	16.2	$	1,380.5
Letters of credit outstanding under letter of credit facility		205.7		90.4		7.0		5.0		—		308.1
Letters of credit outstanding under letter of credit facilities														Letters of credit outstanding under letter of credit facilities	241.5		90.9		3.9		5.0		—		341.3
Letters of credit outstanding under accounts receivable securitization program	Letters of credit outstanding under accounts receivable securitization program	110.4		18.9		4.4		—		—		133.7		Letters of credit outstanding under accounts receivable securitization program	134.2		19.5		10.4		—		—		164.1
Other letters of credit		—		1.4		—		—		—		1.4

		1,609.5		152.8		91.0		35.9		16.4		1,905.6			1,610.3		150.9		70.2		38.3		16.2		1,885.9
Less: Letters of credit in support of surety bonds (4)	Less: Letters of credit in support of surety bonds (4)	(309.7)		(29.8)		—		(1.2)		—		(340.7)		Less: Letters of credit in support of surety bonds (4)	(369.9)		(30.8)		(2.8)		(1.2)		—		(404.7)
Less: Cash collateral in support of surety bonds (4)		(15.0)		—		—		—		—		(15.0)

Obligations supported, net	Obligations supported, net	$	1,284.8	$	123.0	$	91.0	$	34.7	$	16.4	$	1,549.9	Obligations supported, net	$	1,240.4	$	120.1	$	67.4	$	37.1	$	16.2	$	1,481.2

(1) Obligations include pension and health care plans, workers’ compensation, and property and casualty insurance

(2) Obligations pertain to customer and vendor contracts

(3) Obligations primarily pertain to the disturbance or alteration of public roadways in connection with the Company’s mining activities that is subject to future restoration

(4) Serve as collateral for certain surety bonds at the request of surety bond providers. ~~The~~

Not presented in the above table is approximately $105 million of cash collateral posted by the Company ~~has also posted $7.3 million~~and included in ~~incremental~~the accompanying condensed consolidated balance sheets at September 30, 2022. Such collateral is primarily in support of the financial instruments noted above, including in relation to the Company’s collateralized letter of credit agreement, mandatory repurchases of credit facility capacity, additional collateral in support of certain surety bonds, and amounts held directly with ~~the beneficiary that is~~beneficiaries which are not supported by a surety ~~bond.~~bonds.

Financial assurances associated with new reclamation bonding requirements, surety bonds or other obligations may require additional collateral in the form of cash or letters of credit causing a decline in the Company’s liquidity.

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As described in Note ~~16.~~12. “Financial Instruments and Other Guarantees” in the accompanying unaudited condensed consolidated financial statements, the Company is required to provide various forms of financial assurance in support of its mining reclamation obligations in the jurisdictions in which it operates. Such requirements are typically established by statute or under mining permits. Historically, such assurances have taken the form of third-party instruments such as surety bonds, bank guarantees and letters of credit, as well as self-bonding arrangements in the U.S. Self-bonding in the U.S. has become increasingly restricted in recent years, leading to the Company’s increased usage of surety bonds and similar third-party instruments. This change in practice has had an unfavorable impact on its liquidity due to increased collateral requirements and surety and related fees.

At September 30, ~~2021,~~2022, the Company had total asset retirement obligations of ~~$710.2~~$725.8 million which were backed by a combination of surety bonds, bank guarantees and letters of credit.

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.

~~Guarantees and Other Financial Instruments with Off-Balance-Sheet Risk.~~

~~See Note 16. “Financial Instruments and Other Guarantees” in the Company’s unaudited condensed consolidated financial statements for a discussion~~

Table of ~~its accounts receivable securitization program and guarantees and other financial instruments with off-balance-sheet risk.~~Contents

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, ~~revenues~~revenue and expenses and related disclosure of contingent assets and liabilities. On an ongoing basis, the Company evaluates its estimates. The Company bases its estimates on historical experience and on various other assumptions that it believes are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates.

At September 30, 2021, the Company identified certain assets with an aggregate carrying value of approximately $1.1 billion in its Seaborne Metallurgical Mining, Powder River Basin Mining, Other U.S. Thermal Mining and Corporate and Other segments whose recoverability is most sensitive to coal pricing, cost pressures, customer demand, customer concentration risk and future economic viability. The Company conducted a review of those assets as of September 30, 2021 and determined that no impairment charges were necessary as of that date.

The Company’s critical accounting policies and estimates are discussed in 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, ~~2020.~~2021. The Company’s critical accounting policies remain unchanged at September 30, ~~2021.~~2022, and there have been no material changes in the Company’s critical accounting estimates.

Newly Adopted Accounting Standards and Accounting Standards Not Yet Implemented

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

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Coal Pricing Risk

As of September 30, 2022, the Company held coal derivative contracts related to a portion of its forecasted sales with an aggregate notional volume of 1.0 million tonnes. Such financial contracts may include futures, forwards and options. Included in this total are 0.9 million tonnes related to financial derivatives entered to support the profitability of the Wambo Underground Mine as part of a strategy to extend the mine life through mid-2023. Of this total, 0.3 million tonnes will settle in 2022 and 0.6 million tonnes will settle in 2023. The Newcastle thermal coal index was $414.80 per tonne on September 30, 2022, and the Company had posted $379 million of variation margin for the related derivative contracts at such date. A change in the Newcastle forward curve of $100 per tonne would increase or decrease the Company’s variation margin requirement by approximately $86 million and result in comparable unrealized gains or losses.

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 7.6. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements. As of September 30, ~~2021,~~2022, the Company had currency options outstanding with an aggregate notional amount of ~~$595.0~~$855.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending June 30, ~~2022.~~2023. 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 ~~$141~~$208 million for the next twelve months. Based upon the Australian dollar/U.S. dollar exchange rate at September 30, ~~2021,~~2022, the currency option contracts outstanding at that date would limit the Company’s net exposure to a $0.10 unfavorable change in the exchange rate to approximately ~~$125~~$201 million for the next twelve months.

Diesel Fuel Price Risk

Previously, the Company managed price risk of the diesel fuel used in its mining activities through the use of derivatives, primarily swaps. As of September 30, ~~2021,~~2022, the Company did not have any diesel fuel derivative instruments in place. The Company also manages the price risk of diesel fuel through the use of cost pass-through contacts with certain customers.

The Company expects to consume 8095 to 90105 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 ~~$20~~$24 million based on its expected usage.

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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 September 30, ~~2021,~~2022, and concluded that such controls and procedures were effective to provide reasonable assurance that the desired control objectives were achieved. Additionally, there have been no changes to the Company’s internal control over financial reporting during the most recent fiscal quarter that materially affected, or are reasonably likely to materially affect, its internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings.

The Company is subject to various legal and regulatory proceedings. For a description of its significant legal proceedings refer to Note ~~4. “Discontinued Operations” and Note 17.~~13. “Commitments and Contingencies” to the unaudited condensed consolidated financial statements included in Part I, Item 1. “Financial Statements” of this Quarterly Report, which information is incorporated by reference herein.

Item 1A. Risk Factors.

The Company operates in a rapidly changing environment that involves a number of risks. For information regarding factors that could affect the Company's results of operations, financial condition and liquidity, see the risk factors disclosed in Part I, Item 1A. “Risk Factors” in its Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 filed with the SEC on February ~~23, 2021.~~18, 2022. In addition to the other information set forth in this Quarterly Report, including the information presented in 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 filing, which could materially affect the Company’s results of operations, financial condition and liquidity.

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

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

•if a substantial number of the Company’s long-term coal supply agreements, including those with its largest customers, terminate, or if the pricing, volumes or other elements of those agreements materially adjust, its ~~revenues~~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 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;

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•concerns about the impacts of coal combustion on global climate are increasingly leading to ~~consequences~~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;

•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 ~~economically recoverable~~ coal reserves and resources and inaccuracies in its estimates could result in lower than expected ~~revenues,~~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 may undertake further repositioning plans that would require additional charges;~~

•~~the~~ Company’s business, results of operations, financial condition and prospects could be materially and adversely affected by ~~the COVID-19~~ pandemic or other widespread illnesses and the related effects on public health;

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

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

•the Company’s financial performance could be adversely affected by its ~~Indebtedness;~~funded indebtedness (Indebtedness);

•despite the Company’s Indebtedness, it may still be able to incur more debt, which could further increase the risks associated with its Indebtedness;

•the terms of the indentures governing the Company’s senior secured notes and the agreements and instruments governing its other Indebtedness and surety bonding obligations impose restrictions that may limit its operating and financial flexibility;

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•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 and could fall below the minimum allowed by New York Stock Exchange listing requirements;

•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 ~~repurchase~~future repurchases of its stock is dependent on a number of factors and ~~future payments and repurchases~~ 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.

Dividends

The Company suspended dividends in 2020. ~~As more fully described within “Liquidity and Capital Resources” of Part I, Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” during~~During the fourth quarter of 2020, the Company entered into a transaction support ~~agreements~~agreement with its surety bond providers which ~~prohibit~~prohibits the payment of dividends through the earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025) unless otherwise agreed to by the parties to the ~~agreements.~~agreement. Additionally, restrictive covenants in its credit facility and in the indentures governing its senior secured notes also limit the Company’s ability to pay cash dividends.

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

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 (Repurchase Program). On April 25, 2018, the Company announced that the Board authorized the expansion of the Repurchase Program to $1.0 billion. On October 30, 2018, the Company announced that the Board authorized an additional expansion of the Repurchase Program, which was eventually expanded to $1.5 ~~billion.~~billion during 2018. The Repurchase Program does not have an expiration date and may be discontinued at any time. Through September 30, ~~2021,~~2022, the Company has repurchased 41.5 million shares of its common stock for ~~$1,340.3~~$1,340.3 million,, which included commissions paid of ~~$0.8~~$0.8 million,, leaving ~~$160.5~~$160.5 million available for share repurchase under the Repurchase Program.

The Company suspended share repurchases in 2019, and similar to the payment of dividends as described above, the same ~~agreements~~agreement with its surety bond providers ~~prohibit~~prohibits share repurchases through the earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025) unless otherwise agreed to by the parties to the ~~agreements.~~agreement. Additionally, restrictive covenants in its credit facility and in the indentures governing its senior secured notes also limit the Company’s ability to repurchase shares. Prior to the suspension, repurchases were made at the Company’s discretion. The specific timing, price and size of purchases depended upon the share price, general market and economic conditions and other considerations, including compliance with various debt agreements in effect at the time the repurchases were made.

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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. ~~During September 2021, the Company announced that it could offer and sell up~~The at-the-market equity offering program was further expanded to ~~an additional 12.5~~32.5 million shares ~~for a total of 25.0 million shares authorized through the at-the-market offering program.~~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, ~~and~~ September 17, 2021, and December 17, 2021 relating to the offer and sale of the shares. Through September 30, 2022, 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 nine months ended September 30, 2022, 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 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 a prospectus supplement dated March 7, 2022 relating to the offer and sale of the shares. During the nine months ended September 30, ~~2021,~~2022, the Company sold approximately ~~17.1 million shares for net cash proceeds of $177.2 million. Between October 1, 2021 and November 2, 2021, the Company settled sales of an additional 3.2~~10.1 million shares for net proceeds of ~~$43.4 million.~~$222.0 million, thereby concluding this at-the-market equity offering program.

~~Also during the nine months ended September 30,~~

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During 2021, the Company completed multiple bilateral transactions with holders of the 2022 Notes, the 2025 Notes and the 2024 Peabody Notes in which the Company issued an aggregate ~~6.7~~10.0 million shares of its common stock in exchange for $37.3 million aggregate principal amount of the 2022 Notes, ~~$17.9~~$47.2 million aggregate principal amount of the 2025 Notes and ~~$5.5~~$21.6 million aggregate principal amount of the 2024 Peabody Notes. No such bilateral transactions were completed during the nine months ended September 30, 2022. The issuance of shares of common stock in exchange for the 2022 Notes, the 2025 Notes and the 2024 Peabody Notes was made in reliance on the exemption from registration provided in Section 3(a)(9) under the Securities Act of 1933, based in part on representations of holders of the 2022 Notes, the 2025 Notes and the 2024 Peabody Notes, and on the basis that the exchange was completed with existing holders of the Company's securities and no commission or other remuneration was paid or given for soliciting the exchange. Between October 1, 2021 and November 2, 2021, the Company issued an aggregate 1.9 million shares of its common stock in exchange for $19.0 million aggregate principal amount of the 2025 Notes and $12.0 million aggregate principal amount of the Peabody Notes in a similar manner as noted above.

~~Share Relinquishments~~

Purchases of Equity Securities

The following table summarizes all share purchases for the three months ended September 30, ~~2021:~~2022:

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)
July 1 through July 31, 2021 5,073 $ 8.19 — $ 160.5
August 1 through August 31, 2021 — — — 160.5
September 1 through September 30, 2021 — — — 160.5
Total 5,073 8.19 —


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)
July 1 through July 31, 2022	116	$	21.04	—	$	160.5
August 1 through August 31, 2022	—	—		—	160.5
September 1 through September 30, 2022	—	—		—	160.5
Total	116	21.04		—

(1)~~Includes shares~~Shares withheld to cover the withholding taxes upon the vesting of equity awards, which are not part of the Repurchase Program.

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.

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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*						Variation of Employment Contract, dated August 11, 2021, between Peabody Energy Australia Coal Pty Ltd and Darren R. Yeates (Incorporated by reference to Exhibit 99.1 of the Registrant’s Current Report on Form 8-K, filed August 13, 2021).

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 ~~formatted as~~(embedded within the Inline XBRL ~~and contained in Exhibit 101~~document).

*						~~These exhibits constitute all management contracts, compensatory plans and arrangements required to be filed as an exhibit to this form pursuant to Item 15(a)(3) and 15(b) of this report.~~
†						Filed herewith.

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SIGNATURE

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

PEABODY ENERGY CORPORATION

Date:

November ~~5, 2021~~3, 2022

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)

6260


	Three Months Ended September 30, 2020
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	37.1	$	—	$	264.3	$	172.8	$	—	$	474.2
Export	125.7		—		—		—		—		125.7
Total thermal	162.8		—		264.3		172.8		—		599.9
Metallurgical coal

Export	—		78.4		—		—		—		78.4
Total metallurgical	—		78.4		—		—		—		78.4
Other (2)	0.2		0.4		0.5		7.0		(15.4)		(7.3)
Revenues	$	163.0	$	78.8	$	264.8	$	179.8	$	(15.4)	$	671.0


Period Ending December 31,	Operating Leases		Finance Leases
	(Dollars in millions)
2021	$	6.6	$	2.8
2022	18.4		11.1
2023	16.8		5.6
2024	6.0		4.7
2025	3.4		4.5
2026 and thereafter	3.8		9.5
Total lease payments	55.0		38.2
Less imputed interest	(6.4)		(7.8)
Total lease liabilities	$	48.6	$	30.4


	Foreign Currency Translation Adjustment		Prior Service Credit Associated with Postretirement Plans		Total Accumulated Other Comprehensive Income
	(Dollars in millions)
December 31, 2020	$	1.8	$	204.0	$	205.8

Reclassification from other comprehensive income to earnings	—		(33.0)		(33.0)
Current period change	(1.2)		—		(1.2)
September 30, 2021	$	0.6	$	171.0	$	171.6


	Three Months Ended September 30,				Increase to Income				Nine Months Ended September 30,				Increase to Income
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Loss from continuing operations, net of income taxes	$	(59.6)	$	(64.8)	$	5.2	8	%	$	(160.3)	$	(1,739.4)	$	1,579.1	91	%
Income (loss) from discontinued operations, net of income taxes	24.3		(2.3)		26.6		1,157	%	20.0		(6.8)		26.8		394	%
Net loss	(35.3)		(67.1)		31.8		47	%	(140.3)		(1,746.2)		1,605.9		92	%
Less: Net income (loss) attributable to noncontrolling interests	8.9		0.1		8.8		8,800	%	12.6		(5.1)		17.7		347	%
Net loss attributable to common stockholders	$	(44.2)	$	(67.2)	$	23.0	34	%	$	(152.9)	$	(1,741.1)	$	1,588.2	91	%


	Three Months Ended September 30,				Increase to EPS				Nine Months Ended September 30,				Increase to EPS
	2021		2020		$		%		2021		2020		$		%
Diluted EPS attributable to common stockholders:
Loss from continuing operations	$	(0.60)	$	(0.66)	$	0.06	9	%	$	(1.65)	$	(17.76)	$	16.11	91	%
Income (loss) from discontinued operations	0.22		(0.03)		0.25		833	%	0.19		(0.07)		0.26		371	%
Net loss attributable to common stockholders	$	(0.38)	$	(0.69)	$	0.31	45	%	$	(1.46)	$	(17.83)	$	16.37	92	%