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

March 31, ~~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 ~~98.3~~143.8 million shares of the registrant’s common stock (par value of $0.01 per share) outstanding at April ~~30, 2021.~~29, 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			2728
Item 3. Quantitative and Qualitative Disclosures About Market Risk			5049
Item 4. Controls and Procedures			50
PART II — OTHER INFORMATION
Item 1. Legal Proceedings			50
Item 1A. Risk Factors			50
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			5152
Item 4. Mine Safety Disclosures			5253

Item 6. Exhibits			5253
EXHIBIT INDEX			5354
SIGNATURE			55

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


		Three Months Ended March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions, except per share data)						(Dollars in millions, except per share data)
Revenues			$	651.3	$	846.2
Revenue							Revenue		$	691.4	$	651.3
Costs and expenses	Costs and expenses						Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	Operating costs and expenses (exclusive of items shown separately below)		582.6		779.5		Operating costs and expenses (exclusive of items shown separately below)		699.0		582.6
Depreciation, depletion and amortization	Depreciation, depletion and amortization		68.3		106.0		Depreciation, depletion and amortization		72.9		68.3
Asset retirement obligation expenses	Asset retirement obligation expenses		15.9		17.6		Asset retirement obligation expenses		15.0		15.9
Selling and administrative expenses	Selling and administrative expenses		21.7		24.9		Selling and administrative expenses		23.1		21.7
Restructuring charges	Restructuring charges		2.1		6.5		Restructuring charges		1.6		2.1
Transaction costs related to joint ventures			0		4.2

Other operating (income) loss:	Other operating (income) loss:						Other operating (income) loss:
Net loss (gain) on disposals			0.6		(8.1)
Net (gain) loss on disposals							Net (gain) loss on disposals		(4.9)		0.6

Loss from equity affiliates			0.9		9.1
(Income) loss from equity affiliates							(Income) loss from equity affiliates		(44.7)		0.9
Operating loss	Operating loss		(40.8)		(93.5)		Operating loss		(70.6)		(40.8)
Interest expense	Interest expense		52.4		33.1		Interest expense		39.4		52.4
Gain on early debt extinguishment			(3.5)		0
Net loss (gain) on early debt extinguishment							Net loss (gain) on early debt extinguishment		23.5		(3.5)
Interest income	Interest income		(1.5)		(3.1)		Interest income		(0.5)		(1.5)
Net periodic benefit (credit) costs, excluding service cost			(8.7)		2.8
Net periodic benefit credit, excluding service cost							Net periodic benefit credit, excluding service cost		(12.2)		(8.7)

Loss from continuing operations before income taxes	Loss from continuing operations before income taxes		(79.5)		(126.3)		Loss from continuing operations before income taxes		(120.8)		(79.5)
Income tax (benefit) provision			(1.8)		3.0
Income tax benefit							Income tax benefit		(1.0)		(1.8)
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		(77.7)		(129.3)		Loss from continuing operations, net of income taxes		(119.8)		(77.7)
Loss from discontinued operations, net of income taxes	Loss from discontinued operations, net of income taxes		(2.0)		(2.2)		Loss from discontinued operations, net of income taxes		(0.8)		(2.0)
Net loss	Net loss		(79.7)		(131.5)		Net loss		(120.6)		(79.7)

Less: Net income (loss) attributable to noncontrolling interests			0.4		(1.8)
Less: Net (loss) income attributable to noncontrolling interests							Less: Net (loss) income attributable to noncontrolling interests		(1.1)		0.4
Net loss attributable to common stockholders	Net loss attributable to common stockholders		$	(80.1)	$	(129.7)	Net loss attributable to common stockholders		$	(119.5)	$	(80.1)

Loss from continuing operations:	Loss from continuing operations:						Loss from continuing operations:
Basic loss per share	Basic loss per share		$	(0.79)	$	(1.31)	Basic loss per share		$	(0.87)	$	(0.79)
Diluted loss per share	Diluted loss per share		$	(0.79)	$	(1.31)	Diluted loss per share		$	(0.87)	$	(0.79)
Net loss attributable to common stockholders:	Net loss attributable to common stockholders:						Net loss attributable to common stockholders:
Basic loss per share	Basic loss per share		$	(0.81)	$	(1.33)	Basic loss per share		$	(0.88)	$	(0.81)
Diluted loss per share	Diluted loss per share		$	(0.81)	$	(1.33)	Diluted loss per share		$	(0.88)	$	(0.81)

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 March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions)						(Dollars in millions)
Net loss	Net loss		$	(79.7)	$	(131.5)	Net loss		$	(120.6)	$	(79.7)

Postretirement plans (net of $0.0 tax provisions in each period)	Postretirement plans (net of $0.0 tax provisions in each period)		(11.0)		(2.2)		Postretirement plans (net of $0.0 tax provisions in each period)		(13.4)		(11.0)

Foreign currency translation adjustment	Foreign currency translation adjustment		(0.2)		(6.8)		Foreign currency translation adjustment		1.9		(0.2)
Other comprehensive loss, net of income taxes	Other comprehensive loss, net of income taxes		(11.2)		(9.0)		Other comprehensive loss, net of income taxes		(11.5)		(11.2)
Comprehensive loss	Comprehensive loss		(90.9)		(140.5)		Comprehensive loss		(132.1)		(90.9)

Less: Net income (loss) attributable to noncontrolling interests			0.4		(1.8)
Less: Net (loss) income attributable to noncontrolling interests							Less: Net (loss) income attributable to noncontrolling interests		(1.1)		0.4
Comprehensive loss attributable to common stockholders	Comprehensive loss attributable to common stockholders		$	(91.3)	$	(138.7)	Comprehensive loss attributable to common stockholders		$	(131.0)	$	(91.3)

See accompanying notes to unaudited condensed consolidated financial statements.

Table of Contents

PEABODY ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS


		(Unaudited)					(Unaudited)
		March 31, 2021		December 31, 2020			March 31, 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	$	580.2	$	709.2	Cash and cash equivalents	$	823.3	$	954.3
Restricted cash	Restricted cash	43.5		0		Restricted cash	24.7		—
Accounts receivable, net of allowance for credit losses of $0.0 at March 31, 2021 and December 31, 2020		167.8		244.8
Inventories		241.4		261.6
Accounts receivable, net of allowance for credit losses of $0.0 at March 31, 2022 and December 31, 2021						Accounts receivable, net of allowance for credit losses of $0.0 at March 31, 2022 and December 31, 2021	357.4		350.5
Inventories, net						Inventories, net	269.1		226.7

Other current assets	Other current assets	239.2		204.7		Other current assets	331.8		270.2
Total current assets	Total current assets	1,272.1		1,420.3		Total current assets	1,806.3		1,801.7
Property, plant, equipment and mine development, net	Property, plant, equipment and mine development, net	3,025.4		3,051.1		Property, plant, equipment and mine development, net	2,903.3		2,950.6

Operating lease right-of-use assets	Operating lease right-of-use assets	46.8		49.9		Operating lease right-of-use assets	33.0		35.5
Investments and other assets	Investments and other assets	142.0		140.9		Investments and other assets	201.2		162.0
Deferred income taxes		0		4.9

Total assets	Total assets	$	4,486.3	$	4,667.1	Total assets	$	4,943.8	$	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	$	69.4	$	44.9	Current portion of long-term debt	$	19.1	$	59.6

Accounts payable and accrued expenses	Accounts payable and accrued expenses	721.6		745.7		Accounts payable and accrued expenses	798.2		872.1
Total current liabilities	Total current liabilities	791.0		790.6		Total current liabilities	817.3		931.7
Long-term debt, less current portion	Long-term debt, less current portion	1,411.3		1,502.9		Long-term debt, less current portion	1,079.0		1,078.2
Deferred income taxes	Deferred income taxes	34.6		35.0		Deferred income taxes	20.9		27.3
Asset retirement obligations	Asset retirement obligations	658.6		650.5		Asset retirement obligations	659.5		654.8
Accrued postretirement benefit costs	Accrued postretirement benefit costs	410.8		413.2		Accrued postretirement benefit costs	209.6		212.1
Operating lease liabilities, less current portion	Operating lease liabilities, less current portion	37.5		42.1		Operating lease liabilities, less current portion	24.6		27.2
Other noncurrent liabilities	Other noncurrent liabilities	251.0		251.5		Other noncurrent liabilities	236.0		197.7
Total liabilities	Total liabilities	3,594.8		3,685.8		Total liabilities	3,046.9		3,129.0
Stockholders’ equity	Stockholders’ equity					Stockholders’ equity

Preferred Stock — $0.01 per share par value; 100.0 shares authorized, 0 shares issued or outstanding as of March 31, 2021 and December 31, 2020		0		0
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, 0 shares issued or outstanding as of March 31, 2021 and December 31, 2020		0		0
Common Stock — $0.01 per share par value; 450.0 shares authorized, 141.2 shares issued and 98.3 shares outstanding as of March 31, 2021 and 140.5 shares issued and 97.8 shares outstanding as of December 31, 2020		1.4		1.4
Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of March 31, 2022 and December 31, 2021						Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of March 31, 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 March 31, 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 March 31, 2022 and December 31, 2021	—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 187.0 shares issued and 143.8 shares outstanding as of March 31, 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, 187.0 shares issued and 143.8 shares outstanding as of March 31, 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	3,366.4		3,364.6		Additional paid-in capital	3,969.5		3,745.6
Treasury stock, at cost — 42.9 and 42.7 common shares as of March 31, 2021 and December 31, 2020		(1,369.5)		(1,368.9)
Treasury stock, at cost — 43.2 and 43.0 common shares as of March 31, 2022 and December 31, 2021						Treasury stock, at cost — 43.2 and 43.0 common shares as of March 31, 2022 and December 31, 2021	(1,372.3)		(1,370.3)
Accumulated deficit	Accumulated deficit	(1,353.4)		(1,273.3)		Accumulated deficit	(1,032.7)		(913.2)
Accumulated other comprehensive income	Accumulated other comprehensive income	194.6		205.8		Accumulated other comprehensive income	286.4		297.9
Peabody Energy Corporation stockholders’ equity	Peabody Energy Corporation stockholders’ equity	839.5		929.6		Peabody Energy Corporation stockholders’ equity	1,852.8		1,761.8
Noncontrolling interests	Noncontrolling interests	52.0		51.7		Noncontrolling interests	44.1		59.0
Total stockholders’ equity	Total stockholders’ equity	891.5		981.3		Total stockholders’ equity	1,896.9		1,820.8
Total liabilities and stockholders’ equity	Total liabilities and stockholders’ equity	$	4,486.3	$	4,667.1	Total liabilities and stockholders’ equity	$	4,943.8	$	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

		Three Months Ended March 31,					Three Months Ended March 31,
		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	Net loss	$	(79.7)	$	(131.5)	Net loss	$	(120.6)	$	(79.7)
Loss from discontinued operations, net of income taxes	Loss from discontinued operations, net of income taxes	2.0		2.2		Loss from discontinued operations, net of income taxes	0.8		2.0
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes	(77.7)		(129.3)		Loss from continuing operations, net of income taxes	(119.8)		(77.7)
Adjustments to reconcile loss from continuing operations, net of income taxes to net cash provided by (used in) operating activities:
Adjustments to reconcile loss from continuing operations, net of income taxes to net cash (used in) provided by operating activities:						Adjustments to reconcile loss from continuing operations, net of income taxes to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	Depreciation, depletion and amortization	68.3		106.0		Depreciation, depletion and amortization	72.9		68.3
Noncash interest expense, net	Noncash interest expense, net	4.9		4.0		Noncash interest expense, net	3.8		4.9
Noncash coal inventory revaluation		5.5		0

Deferred income taxes	Deferred income taxes	(0.4)		(3.4)		Deferred income taxes	(6.4)		(0.4)
Noncash share-based compensation	Noncash share-based compensation	1.8		2.2		Noncash share-based compensation	2.0		1.8

Net loss (gain) on disposals		0.6		(8.1)
Gain on early debt extinguishment		(3.5)		0
Loss from equity affiliates		0.9		9.1
Net (gain) loss on disposals						Net (gain) loss on disposals	(4.9)		0.6
Net loss (gain) on early debt extinguishment						Net loss (gain) on early debt extinguishment	23.5		(3.5)
(Income) loss from equity affiliates						(Income) loss from equity affiliates	(44.7)		0.9

Foreign currency option contracts	Foreign currency option contracts	2.9		0.9		Foreign currency option contracts	(3.3)		2.9
Changes in current assets and liabilities:	Changes in current assets and liabilities:					Changes in current assets and liabilities:
Accounts receivable	Accounts receivable	77.0		64.2		Accounts receivable	(6.9)		77.0
Inventories	Inventories	14.8		62.4		Inventories	(42.4)		20.3
Other current assets	Other current assets	1.6		17.5		Other current assets	(80.0)		1.6
Accounts payable and accrued expenses	Accounts payable and accrued expenses	(15.4)		(125.1)		Accounts payable and accrued expenses	(28.4)		(15.4)
Collateral arrangements	Collateral arrangements	(5.3)		0		Collateral arrangements	(28.7)		(5.3)
Asset retirement obligations	Asset retirement obligations	8.1		6.4		Asset retirement obligations	4.7		8.1
Workers’ compensation obligations	Workers’ compensation obligations	0.6		(0.8)		Workers’ compensation obligations	(0.6)		0.6
Postretirement benefit obligations	Postretirement benefit obligations	(13.4)		(7.9)		Postretirement benefit obligations	(15.9)		(13.4)
Pension obligations	Pension obligations	2.8		0.1		Pension obligations	(0.6)		2.8
Other, net	Other, net	0		0.2		Other, net	3.2		—
Net cash provided by (used in) continuing operations		74.1		(1.6)
Net cash (used in) provided by continuing operations						Net cash (used in) provided by continuing operations	(272.5)		74.1
Net cash used in discontinued operations	Net cash used in discontinued operations	(3.1)		(3.1)		Net cash used in discontinued operations	(1.2)		(3.1)
Net cash provided by (used in) operating activities		71.0		(4.7)
Net cash (used in) provided by operating activities						Net cash (used in) provided by operating activities	(273.7)		71.0

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)

		Three Months Ended March 31,					Three Months Ended March 31,
		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	(50.3)		(31.3)		Additions to property, plant, equipment and mine development	(29.7)		(50.3)
Changes in accrued expenses related to capital expenditures	Changes in accrued expenses related to capital expenditures	(11.4)		(11.4)		Changes in accrued expenses related to capital expenditures	(7.0)		(11.4)

Proceeds from disposal of assets, net of receivables	Proceeds from disposal of assets, net of receivables	0.9		10.5		Proceeds from disposal of assets, net of receivables	3.6		0.9

Contributions to joint ventures	Contributions to joint ventures	(136.1)		(96.3)		Contributions to joint ventures	(126.6)		(136.1)
Distributions from joint ventures	Distributions from joint ventures	102.4		98.4		Distributions from joint ventures	148.2		102.4
Advances to related parties		0		(6.9)
Cash receipts from Middlemount Coal Pty Ltd		2.3		0

Cash receipts from Middlemount Coal Pty Ltd and other related parties						Cash receipts from Middlemount Coal Pty Ltd and other related parties	47.2		2.3

Other, net	Other, net	(1.0)		(0.1)		Other, net	(0.5)		(1.0)
Net cash used in investing activities		(93.2)		(37.1)
Net cash provided by (used in) investing activities						Net cash provided by (used in) investing activities	35.2		(93.2)
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	545.0		—
Repayments of long-term debt	Repayments of long-term debt	(40.2)		(7.2)		Repayments of long-term debt	(599.9)		(40.2)
Payment of debt issuance and other deferred financing costs	Payment of debt issuance and other deferred financing costs	(22.5)		0		Payment of debt issuance and other deferred financing costs	(19.2)		(22.5)

Proceeds from common stock issuances, net of costs						Proceeds from common stock issuances, net of costs	222.0		—
Repurchase of employee common stock relinquished for tax withholding	Repurchase of employee common stock relinquished for tax withholding	(0.6)		(0.8)		Repurchase of employee common stock relinquished for tax withholding	(2.0)		(0.6)

Distributions to noncontrolling interests	Distributions to noncontrolling interests	(0.1)		(0.1)		Distributions to noncontrolling interests	(13.8)		(0.1)
Other, net	Other, net	0.1		0.2		Other, net	0.1		0.1
Net cash used in financing activities		(63.3)		(7.9)
Net cash provided by (used in) financing activities						Net cash provided by (used in) financing activities	132.2		(63.3)
Net change in cash, cash equivalents and restricted cash	Net change in cash, cash equivalents and restricted cash	(85.5)		(49.7)		Net change in cash, cash equivalents and restricted cash	(106.3)		(85.5)
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	Cash, cash equivalents and restricted cash at end of period	$	623.7	$	682.5	Cash, cash equivalents and restricted cash at end of period	$	848.0	$	623.7

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 March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions, except per share data)						(Dollars in millions)

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

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

Share-based compensation for equity-classified awards	Share-based compensation for equity-classified awards		1.8		2.2		Share-based compensation for equity-classified awards		2.0		1.8

Common stock issuances, net of costs							Common stock issuances, net of costs		221.9		—

Balance, end of period	Balance, end of period		3,366.4		3,353.3		Balance, end of period		3,969.5		3,366.4
Treasury stock	Treasury stock						Treasury stock
Balance, beginning of period	Balance, beginning of period		(1,368.9)		(1,367.3)		Balance, beginning of period		(1,370.3)		(1,368.9)

Repurchase of employee common stock relinquished for tax withholding	Repurchase of employee common stock relinquished for tax withholding		(0.6)		(0.8)		Repurchase of employee common stock relinquished for tax withholding		(2.0)		(0.6)
Balance, end of period	Balance, end of period		(1,369.5)		(1,368.1)		Balance, end of period		(1,372.3)		(1,369.5)
(Accumulated deficit) retained earnings
Accumulated deficit							Accumulated deficit
Balance, beginning of period	Balance, beginning of period		(1,273.3)		597.0		Balance, beginning of period		(913.2)		(1,273.3)
Net loss attributable to common stockholders	Net loss attributable to common stockholders		(80.1)		(129.7)		Net loss attributable to common stockholders		(119.5)		(80.1)

Balance, end of period	Balance, end of period		(1,353.4)		467.3		Balance, end of period		(1,032.7)		(1,353.4)
Accumulated other comprehensive income	Accumulated other comprehensive income						Accumulated other comprehensive income
Balance, beginning of period	Balance, beginning of period		205.8		31.6		Balance, beginning of period		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)		(2.2)		Postretirement plans (net of $0.0 tax provisions in each period)		(13.4)		(11.0)
Foreign currency translation adjustment	Foreign currency translation adjustment		(0.2)		(6.8)		Foreign currency translation adjustment		1.9		(0.2)
Balance, end of period	Balance, end of period		194.6		22.6		Balance, end of period		286.4		194.6
Noncontrolling interests	Noncontrolling interests						Noncontrolling interests
Balance, beginning of period	Balance, beginning of period		51.7		58.7		Balance, beginning of period		59.0		51.7
Net income (loss) attributable to noncontrolling interests			0.4		(1.8)
Net (loss) income attributable to noncontrolling interests							Net (loss) income attributable to noncontrolling interests		(1.1)		0.4
Distributions to noncontrolling interests	Distributions to noncontrolling interests		(0.1)		(0.1)		Distributions to noncontrolling interests		(13.8)		(0.1)
Balance, end of period	Balance, end of period		52.0		56.8		Balance, end of period		44.1		52.0
Total stockholders’ equity	Total stockholders’ equity		$	891.5	$	2,533.3	Total stockholders’ equity		$	1,896.9	$	891.5

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 months ended March 31, ~~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,~~(“ASU”) 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 11. “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 will require 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~~diluted earnings per share, which may increase their dilutive impact compared to the ~~requirements effective January 1, 2021. The adoption of this ASU did not have a material impact on the Company’s consolidated financial statements or disclosures.~~prior accounting model.

Accounting Standards Not Yet Implemented

~~Effects of~~ Reference Rate Reform. In March 2020, ASU 2020-04 was issued, which provides temporary optional expedients to applying the reference rate reform guidance ~~for a limited period of time~~ to ~~ease the potential burden on accounting for~~contracts that reference London Interbank Offered Rate (LIBOR) or another reference rate expected to be discontinued. Under this update, contract modifications ~~caused by~~resulting in a new reference rate ~~reform.~~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. In January 2021, the FASB issued ASU 2021-01 to permit entities to elect certain optional expedients and exceptions when accounting for derivative contracts and certain hedging relationships affected by changes in the interest rates used for discounting cash flows, for computing variation margin settlements, and for calculation price alignment interest in connection with reference rate reform activities.similar secured or unsecured overnight financing rate. The Company ~~is still completing its evaluation of~~cannot estimate the impact of such variable rates on its consolidated financial statements.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Government Assistance. In November 2021, ASU ~~2020-04~~2021-10 was issued, which aims to provide increased transparency by requiring business entities to disclose information about certain types of government assistance they receive in the notes to the financial statements. The guidance is effective for annual periods beginning after December 15, 2021, with early application permitted. The Company did not early adopt the guidance in ASU 2021-10 and ~~ASU 2021-01 and plans to elect optional expedients as reference rate reform activities occur. While the Company is still evaluating, it~~ does not expect the guidance to have a material impact on its ~~consolidated financial statements or~~ disclosures.

(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 March 31, 2021													Three Months Ended March 31, 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	$	44.1	$	0	$	228.4	$	146.8	$	0	$	419.3	Domestic	$	40.4	$	—	$	251.5	$	199.9	$	—	$	491.8
Export	Export	131.9		0		0		0		0		131.9		Export	210.5		—		—		—		—		210.5
Total thermal	Total thermal	176.0		0		228.4		146.8		0		551.2		Total thermal	250.9		—		251.5		199.9		—		702.3
Metallurgical coal	Metallurgical coal													Metallurgical coal
Domestic		0		2.7		0		0		0		2.7

Export	Export	0		83.9		0		0		0		83.9		Export	—		318.0		—		—		—		318.0
Total metallurgical	Total metallurgical	0		86.6		0		0		0		86.6		Total metallurgical	—		318.0		—		—		—		318.0
Other (2)	Other (2)	0.4		0.9		0		2.5		9.7		13.5		Other (2)	0.3		3.3		(0.3)		3.2		(335.4)		(328.9)
Revenues		$	176.4	$	87.5	$	228.4	$	149.3	$	9.7	$	651.3
Revenue														Revenue	$	251.2	$	321.3	$	251.2	$	203.1	$	(335.4)	$	691.4


		Three Months Ended March 31, 2020													Three Months Ended March 31, 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	$	36.5	$	0	$	266.6	$	184.6	$	0	$	487.7	Domestic	$	44.1	$	—	$	228.4	$	146.8	$	—	$	419.3
Export	Export	163.7		0		0		0		0		163.7		Export	131.9		—		—		—		—		131.9
Total thermal	Total thermal	200.2		0		266.6		184.6		0		651.4		Total thermal	176.0		—		228.4		146.8		—		551.2
Metallurgical coal	Metallurgical coal													Metallurgical coal

Export	Export	0		192.5		0		0		0		192.5		Export	—		86.6		—		—		—		86.6
Total metallurgical	Total metallurgical	0		192.5		0		0		0		192.5		Total metallurgical	—		86.6		—		—		—		86.6
Other (2)	Other (2)	0.9		0.7		0		7.7		(7.0)		2.3		Other (2)	0.4		0.9		—		2.5		9.7		13.5
Revenues		$	201.1	$	193.2	$	266.6	$	192.3	$	(7.0)	$	846.2
Revenue														Revenue	$	176.4	$	87.5	$	228.4	$	149.3	$	9.7	$	651.3

(1) Corporate and Other revenue includes ~~gains and~~net losses related to unrealized mark-to-market adjustments ~~from economic hedge activities intended~~on derivatives related to ~~hedge future coal sales.~~forecasted sales and other financial trading activity of $290.2 million and $4.9 million during the three months ended March 31, 2022 and 2021, respectively. Refer to Note 7. “Derivatives and Fair Value Measurements” for additional ~~information regarding~~information. Also included in Corporate and Other revenue is revenue with customers of $19.0 million and $17.9 million during the ~~economic hedge activities.~~three months ended March 31, 2022 and 2021, respectively.

(2) Other includes ~~revenues~~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.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The Company recorded revenue related to delivered coal to customers of approximately $1,039 million and $656 million during the three months ended March 31, 2022 and 2021, respectively. Such amounts exclude unrealized and realized gains and losses on derivative contracts related to forecasted sales and certain other revenue unrelated to delivered coal.

Committed Revenue from Contracts with Customers

The Company expects to recognize revenue subsequent to March 31, ~~2021~~2022 of approximately ~~$3.6~~$5.1 billion related to contracts with customers in which volumes and prices per ton were fixed or reasonably estimable at March 31, ~~2021.~~2022. Approximately ~~45%~~48% of such amount is expected to be recognized over the next twelve months and the remainder thereafter. Actual revenue related 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.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

Accounts Receivable

“Accounts receivable, net” at March 31, ~~2021~~2022 and December 31, ~~2020~~2021 consisted of the following:


		March 31, 2021		December 31, 2020			March 31, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Trade receivables, net	Trade receivables, net	$	131.2	$	180.9	Trade receivables, net	$	323.4	$	307.0
Miscellaneous receivables, net	Miscellaneous receivables, net	36.6		63.9		Miscellaneous receivables, net	34.0		43.5
Accounts receivable, net	Accounts receivable, net	$	167.8	$	244.8	Accounts receivable, net	$	357.4	$	350.5

~~Trade~~NaN of the above receivables ~~net~~ included ~~0 allowance~~allowances for credit losses ~~as of both~~at March 31, ~~2021 and~~2022 or December 31, ~~2020. Miscellaneous receivables, net included 0 allowance for credit losses as of both March 31, 2021 and December 31, 2020.~~2021. NaN charges for credit losses were recognized during the three months ended March 31, ~~2021 and 2020.~~2022 or 2021.

(4) Discontinued Operations

~~Discontinued~~Historically, discontinued operations ~~include~~included 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.

Summarized Results of Discontinued Operations

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

Three Months Ended March 31,
2021 2020
(Dollars in millions)
Loss from discontinued operations, net of income taxes $ (2.0) $ (2.2)


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Loss from discontinued operations, net of income taxes		$	(0.8)	$	(2.0)

Liabilities of Discontinued Operations

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


		March 31, 2021		December 31, 2020			March 31, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Liabilities:	Liabilities:					Liabilities:
Accounts payable and accrued expenses	Accounts payable and accrued expenses	$	62.8	$	62.3	Accounts payable and accrued expenses	$	45.0	$	45.0
Other noncurrent liabilities	Other noncurrent liabilities	85.0		91.4		Other noncurrent liabilities	58.7		59.0
Total liabilities classified as discontinued operations	Total liabilities classified as discontinued operations	$	147.8	$	153.7	Total liabilities classified as discontinued operations	$	103.7	$	104.0

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

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.

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 ~~$89.8~~$87.1 million and ~~$90.1~~$87.2 million at March 31, ~~2021~~2022 and December 31, ~~2020,~~2021, 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 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.

(5) Inventories

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


		March 31, 2021		December 31, 2020			March 31, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Materials and supplies		$	104.3	$	102.6
Materials and supplies, net						Materials and supplies, net	$	112.8	$	102.1
Raw coal	Raw coal	52.4		70.5		Raw coal	46.9		54.6
Saleable coal	Saleable coal	84.7		88.5		Saleable coal	109.4		70.0
Total		$	241.4	$	261.6
Inventories, net						Inventories, net	$	269.1	$	226.7

Materials and supplies inventories, net presented above have been shown net of reserves of ~~$10.5 million and $10.4~~$9.0 million as of both March 31, ~~2021~~2022 and December ~~31, 2020, respectively. The coal inventory balances above are presented net of net realizable value adjustments of $5.5 million as of March~~ 31, 2021.

(6) Equity Method Investments

The Company had total equity method investments and financing receivables of ~~$21.2~~$62.9 million and ~~$24.6~~$62.2 million reflected in “Investments and other assets” in the condensed consolidated balance sheets as of March 31, ~~2021~~2022 and December 31, ~~2020,~~2021, respectively, related to Middlemount Coal Pty Ltd (Middlemount). Included in ~~“Loss~~“(Income) loss from equity affiliates” in the unaudited condensed consolidated statements of operations were ~~losses~~gains related to Middlemount of ~~$0.9 million~~ ~~and~~ ~~$9.1~~$45.1 million during the three months ended March 31, ~~2021~~2022, and ~~2020, respectively.~~losses of $0.9 million during the three months ended March 31, 2021.

The Company received cash payments from Middlemount of $47.0 million and $2.3 million during the three months ended March 31, ~~2021. NaN payments were received from from Middlemount during the three months ended March 31, 2020.~~2022 and 2021, respectively.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

One of the Company’s Australian subsidiaries and the other shareholder of Middlemount are parties to an agreement, as amended from time to time, to provide a revolving loan (Revolving Loans) to Middlemount. The Company’s participation in the Revolving Loans will not, at any time, exceed its 50% equity interest of the revolving loan ~~limit. At March 31, 2021, the revolving loan~~ limit, which was $~~160~~50 million Australian dollars ~~and the Revolving Loans were not fully drawn upon by Middlemount.~~ at March 31, 2022. The Revolving Loans bear interest at 10% per annum and expire on December 31, ~~2021.~~2023. The ~~value of the portion of the~~ Revolving Loans ~~due to the Company’s Australian subsidiary~~ ~~was $43.3 million and~~ ~~$46.2 million~~were not drawn upon by Middlemount as of either March 31, ~~2021 and~~ 2022 or December 31, ~~2020, respectively, with the decrease during the three months ended March 31, 2021 primarily attributable to payments made by Middlemount.~~2021.

As of both March 31, ~~2021~~2022 and December 31, ~~2020,~~2021, 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) Derivatives and Fair Value Measurements

Derivatives

~~Corporate Risk Management Activities~~

From time to time, the Company may utilize various types of derivative instruments to manage its exposure to risks in the normal course of business, including (1) foreign currency exchange rate risk and the variability of cash flows associated with forecasted Australian dollar expenditures made in its Australian mining platform, (2) price risk of fluctuating coal prices related to forecasted sales or purchases of coal, or changes in the fair value of a fixed price physical sales contract, (3) price risk and the variability of cash flows related to forecasted diesel fuel purchased for use in its operations and (4) interest rate risk on long-term debt. These risk management activities are actively monitored for compliance with the Company’s risk management policies.

On a limited basis, the Company engages in the direct and brokered trading of coal and freight-related contracts. Except those contracts for which the Company has elected to apply a normal purchases and normal sales exception, all derivative coal trading contracts are accounted for at fair value. The Company had 0 diesel fuel or interest rate derivatives in place as of March 31, 2022.

Foreign Currency Option Contracts

As of March 31, ~~2021,~~2022, the Company had currency options outstanding with an aggregate notional amount of ~~$575.0~~$705.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending December 31, ~~2021.~~2022. 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 $0.76 to ~~$0.81~~$0.80 over the nine-month period ending December 31, ~~2021.~~2022.

Derivative Contracts Related to Forecasted Sales

As of March 31, ~~2021,~~2022, the Company held ~~coal-related financial~~coal derivative contracts related to a portion of its forecasted sales ~~for~~with an aggregate notional volume of ~~1.5~~1.6 million tonnes. Such financial contracts may include futures, forwards and options. Included in this total are 1.3 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 ~~the aggregate notional volume, 0.5~~this total, 0.6 million tonnes will settle in ~~2021~~2022 and ~~the remainder~~0.7 million tonnes will settle in 2023 at expected average pricing of approximately $84 per tonne (Newcastle index). The remaining 0.3 million tonnes aggregate notional volume related to other coal financial contracts will settle in 2022. Additionally, the Company classifies certain physical forward sales contracts as derivatives for which the normal purchase, normal sales exception does not apply.

~~The Company had 0 diesel fuel or interest rate derivatives in place as of~~During the three months ended March 31, ~~2021.~~2022, the Company recorded an unrealized mark-to-market loss of $301.0 million on these coal derivative contracts, which includes approximately $237 million of unrealized mark-to-market losses on financial derivatives, and approximately $64 million on physical forward sales contracts.

~~Coal~~Financial Trading ~~Activities~~Contracts

On a limited basis, the Company ~~engages in the direct and brokered trading of~~may enter coal ~~and freight-related contracts (coal trading). Except those~~or freight derivative contracts for ~~which the~~trading purposes. Such financial contracts may include futures, forwards and options. The Company ~~has elected to apply a normal purchases and normal sales exception, all derivative coal~~held nominal financial trading contracts ~~are accounted for at fair value.~~as of March 31, 2022.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Tabular Derivatives Disclosures

The Company has master netting agreements with certain of its counterparties which allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default or termination. Such netting arrangements reduce the Company’s credit exposure related to these counterparties. For classification purposes, the Company records the net fair value of all the positions with a given counterparty as a net asset or liability in the condensed consolidated balance sheets. The fair value of derivatives reflected in the accompanying condensed consolidated balance sheets are set forth in the table below.

March 31, 2021 December 31, 2020
Asset Derivative Liability Derivative Asset Derivative Liability Derivative
(Dollars in millions)
Foreign currency option contracts $ 2.7 $ 0 $ 10.3 $ 0
Coal contracts related to forecasted sales 1.1 (8.6) 0.9 (8.8)
Coal trading contracts 30.4 (35.5) 23.4 (23.1)
Total derivatives 34.2 (44.1) 34.6 (31.9)
Effect of counterparty netting (44.1) 44.1 (30.2) 30.2
Variation margin posted 13.6 0 6.5 0
Net derivatives and margin as classified in the balance sheets $ 3.7 $ 0 $ 10.9 $ (1.7)


	March 31, 2022				December 31, 2021
	Asset Derivative		Liability Derivative		Asset Derivative		Liability Derivative
	(Dollars in millions)
Foreign currency option contracts	$	6.3	$	—	$	1.4	$	—
Derivative contracts related to forecasted sales	133.2		(558.1)		59.5		(184.2)
Financial trading contracts	13.5		—		3.4		—
Total derivatives	153.0		(558.1)		64.3		(184.2)
Effect of counterparty netting	(133.2)		133.2		(59.5)		59.5
Variation margin (received) posted	(13.5)		360.6		(3.4)		95.2
Net derivatives and variation margin as classified in the balance sheets	$	6.3	$	(64.3)	$	1.4	$	(29.5)

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 March 31, 2022, the Company had posted $481.7 million aggregate margin cash, consisting of $347.1 million variation margin cash and $134.6 million initial margin. As of December 31, 2021, the Company had posted $130.1 million aggregate margin cash, consisting of $91.8 million variation margin cash and $38.3 million initial margin.

To reduce exposure to additional margin requirements, subsequent to March 31, 2022, the Company converted 0.8 million metric tons of financial hedges into fixed price physical sales over the next 12 months, eliminating further margin requirements on these tons. With these transactions, 1.4 million metric tons remain outstanding with 0.9 million metric tons projected to settle over the remainder of 2022.

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 ~~Company had a current asset representing cash collateral held as~~amounts of initial margin ~~for derivative positions primarily related to coal derivatives of $6.5 million and $3.0 million at March 31, 2021 and December 31, 2020, respectively. These amounts~~ are not included with the derivatives presented in the ~~table~~tabular disclosures above and are included in “Other current assets” in the accompanying condensed consolidated balance sheets.

1112

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Currently, the Company does not seek cash flow hedge accounting treatment for its ~~currency- or coal-related~~ derivative financial instruments and thus changes in fair value are reflected in current earnings.

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

Three Months Ended March 31, 2021
Total (loss) gain recognized in income Gain realized in income on derivatives Unrealized loss recognized in income on derivatives
Financial Instrument
(Dollars in millions)
Foreign currency option contracts $ (2.9) $ 4.7 $ (7.6)
Coal contracts related to forecasted sales 8.2 10.0 (1.8)
Coal trading contracts (0.7) 2.4 (3.1)
Total $ 4.6 $ 17.1 $ (12.5)
Three Months Ended March 31, 2020
Total loss recognized in income (Loss) gain realized in income on derivatives Unrealized gain (loss) recognized in income on derivatives
Financial Instrument
(Dollars in millions)
Foreign currency option contracts $ (0.9) $ (1.0) $ 0.1
Coal contracts related to forecasted sales (8.6) (6.4) (2.2)
Coal trading contracts (0.1) 4.1 (4.2)
Total $ (9.6) $ (3.3) $ (6.3)


		Three Months Ended March 31, 2022
		Total gain (loss) recognized in income		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	$	2.3	$	(1.0)	$	3.3
Derivative contracts related to forecasted sales	Revenue	(369.0)		(68.0)		(301.0)
Financial trading contracts	Revenue	10.1		(0.7)		10.8
Total		$	(356.6)	$	(69.7)	$	(286.9)

		Three Months Ended March 31, 2021 (1)
		Total loss recognized in income		Gain (loss) realized in income on derivatives		Unrealized loss recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(2.9)	$	4.7	$	(7.6)
Derivative contracts related to forecasted sales	Revenue	(9.7)		(7.9)		(1.8)
Financial trading contracts	Revenue	(0.7)		2.4		(3.1)
Total		$	(13.3)	$	(0.8)	$	(12.5)

~~During~~(1) ‘Results realized in income on derivatives’ has been revised to exclude revenue arising from coal deliveries earned by the Company’s trading and brokerage function of $17.9 million for the three months ended March 31, 2021, ~~and 2020, gains and losses on foreign currency option contracts were included in “Operating costs and expenses,” and gains and losses on coal contracts related~~ to ~~forecasted sales and those related~~be comparable to ~~coal trading contracts were included in “Revenues” in~~ the ~~accompanying unaudited condensed consolidated statements~~presentation of ~~operations.~~the 2022 amounts.

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

Fair Value Measurements

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

1213

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 ~~financial~~(liability) asset positions for which fair value is measured on a recurring ~~basis:~~basis. Variation margin cash associated with the derivative balances is excluded from this table.

March 31, 2021
Level 1 Level 2 Level 3 Total
(Dollars in millions)
Foreign currency option contracts $ 0 $ 2.7 $ 0 $ 2.7
Coal contracts related to forecasted sales 0 (7.5) 0 (7.5)
Coal trading contracts 0 8.5 0 8.5
Equity securities 0 0 4.0 4.0
Total net financial assets $ 0 $ 3.7 $ 4.0 $ 7.7
December 31, 2020
Level 1 Level 2 Level 3 Total
(Dollars in millions)
Foreign currency option contracts $ 0 $ 10.3 $ 0 $ 10.3
Coal contracts related to forecasted sales 0 (7.9) 0 (7.9)
Coal trading contracts 0 6.8 0 6.8
Equity securities 0 0 4.0 4.0
Total net financial assets $ 0 $ 9.2 $ 4.0 $ 13.2


	March 31, 2022
	Level 1		Level 2		Level 3		Total
	(Dollars in millions)
Foreign currency option contracts	$	—	$	6.3	$	—	$	6.3
Derivative contracts related to forecasted sales	—		(424.9)		—		(424.9)
Financial trading contracts	—		13.5		—		13.5
Equity securities	—		—		4.0		4.0
Total net (liabilities) assets	$	—	$	(405.1)	$	4.0	$	(401.1)

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

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.

•~~Coal~~Derivative contracts related to forecasted sales and ~~coal~~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 March 31, ~~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).

Table of Contents

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, which have been limited~~transactions.


	March 31, 2022		December 31, 2021
	(Dollars in millions)
Total debt at par value	$	1,129.9	$	1,173.2
Less: Unamortized debt issuance costs and original issue discount	(31.8)		(35.4)
Net carrying amount	$	1,098.1	$	1,137.8

Estimated fair value	$	1,277.3	$	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 ~~recent history.~~

March 31, 2021 December 31, 2020
(Dollars in millions)
Total debt at par value $ 1,538.2 $ 1,591.3
Less: Unamortized debt issuance costs and original issue discount (57.5) (43.5)
Net carrying amount $ 1,480.7 $ 1,547.8
Estimated fair value $ 862.1 $ 987.6

~~Table~~the number of ~~Contents~~

~~PEABODY ENERGY CORPORATION~~

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

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 months ended March 31, ~~2021~~2022 and ~~2020.~~2021. The Company’s policy is to value all transfers between levels using the beginning of period valuation.

(8) Property, Plant, Equipment and Mine Development

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


		March 31, 2021		December 31, 2020			March 31, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
Land and coal interests	Land and coal interests	$	2,484.1	$	2,482.9	Land and coal interests	$	2,494.1	$	2,494.1
Buildings and improvements	Buildings and improvements	484.7		481.0		Buildings and improvements	590.2		550.8
Machinery and equipment	Machinery and equipment	1,442.5		1,408.5		Machinery and equipment	1,370.9		1,386.2
Less: Accumulated depreciation, depletion and amortization	Less: Accumulated depreciation, depletion and amortization	(1,385.9)		(1,321.3)		Less: Accumulated depreciation, depletion and amortization	(1,551.9)		(1,480.5)
Property, plant, equipment and mine development, net	Property, plant, equipment and mine development, net	$	3,025.4	$	3,051.1	Property, plant, equipment and mine development, net	$	2,903.3	$	2,950.6

Asset Impairment and Other At-Risk Assets

The Company has identified certain assets with an aggregate carrying value of approximately ~~$1.2~~$0.5 billion at March 31, ~~2021~~2022 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 ~~for recoverability~~ as of March 31, ~~2021~~2022 and determined that 0no impairment charges were necessary as of that date.

(9) Leases

The Company has operating and finance leases 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,~~2021, for the Company’s policies regarding “Leases.”

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 0no amounts could be recovered from third parties.

The components of lease expense during the three months ended March 31, 2022 and 2021 were as follows:


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Operating lease cost:
Operating lease cost		$	4.7	$	6.0
Short-term lease cost		6.3		3.4
Variable lease cost		1.6		0.5
Sublease income		(0.4)		(0.5)
Total operating lease cost		$	12.2	$	9.4

Finance lease cost:
Amortization of right-of-use assets		$	1.5	$	0.6
Interest on lease liabilities		0.6		0.5
Total finance lease cost		$	2.1	$	1.1

1416

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Supplemental balance sheet information related to leases at March 31, 2022 and December 31, 2021 was as follows:


	March 31, 2022			December 31, 2021
	(Dollars in millions)
Operating leases:
Operating lease right-of-use assets	$	33.0		$	35.5

Accounts payable and accrued expenses	$	16.1		$	16.4
Operating lease liabilities, less current portion	24.6			27.2
Total operating lease liabilities	$	40.7		$	43.6

Finance leases:
Property, plant, equipment and mine development	$	32.4		$	32.2
Accumulated depreciation	(9.0)			(7.4)
Property, plant, equipment and mine development, net	$	23.4		$	24.8

Current portion of long-term debt	$	15.0		$	15.3
Long-term debt, less current portion	12.6			14.0
Total finance lease liabilities	$	27.6		$	29.3

Weighted average remaining lease term (years)
Operating leases	2.9
Finance leases	6.7

Weighted average discount rate
Operating leases	7.0		%
Finance leases	8.2		%

Supplemental cash flow information related to leases during the three months ended March 31, 2022 and 2021 was as follows:


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases		$	5.9	$	8.3
Operating cash flows for finance leases		0.6		0.7
Financing cash flows for finance leases		2.2		1.3

Right-of-use assets obtained in exchange for lease obligations:
Operating leases		1.6		3.1
Finance leases		—		3.6

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The ~~components of lease expense during the three months ended March 31, 2021 and 2020 were as follows:~~

Three Months Ended March 31,
2021 2020
(Dollars in millions)
Operating lease cost:
Operating lease cost $ 6.0 $ 8.6
Short-term lease cost 3.4 9.9
Variable lease cost 0.5 1.0
Sublease income (0.5) 0
Total operating lease cost $ 9.4 $ 19.5
Finance lease cost:
Amortization of right-of-use assets $ 0.6 $ 3.4
Interest on lease liabilities 0.5 0.2
Total finance lease cost $ 1.1 $ 3.6

~~Supplemental balance sheet information related to leases at March 31, 2021 and December 31, 2020 was as follows:~~

March 31, 2021 December 31, 2020
(Dollars in millions)
Operating leases:
Operating lease right-of-use assets $ 46.8 $ 49.9
Accounts payable and accrued expenses $ 21.1 $ 24.5
Operating lease liabilities, less current portion 37.5 42.1
Total operating lease liabilities $ 58.6 $ 66.6
Finance leases:
Property, plant, equipment and mine development $ 13.8 $ 20.4
Accumulated depreciation (3.1) (2.5)
Property, plant, equipment and mine development, net $ 10.7 $ 17.9
Current portion of long-term debt $ 5.9 $ 21.5
Long-term debt, less current portion 11.4 5.8
Total finance lease liabilities $ 17.3 $ 27.3
Weighted average remaining lease term (years)
Operating leases 3.4
Finance leases 8.2
Weighted average discount rate
Operating leases 6.7 %
Finance leases 10.1 %

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

~~Supplemental cash flow information related to leases during the three months ended March 31, 2021 and 2020 was as follows:~~

Three Months Ended March 31,
2021 2020
(Dollars in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases $ 8.3 $ 12.8
Operating cash flows for finance leases 0.7 0.2
Financing cash flows for finance leases 1.3 5.8
Right-of-use assets obtained in exchange for lease obligations:
Operating leases 3.1 1.3
Finance leases 3.6 0.1

~~The~~ Company's leases have remaining lease terms ranging from less than 1 year to ~~21.0~~19.8 years, ~~years, some of which~~and may include options to extend the terms, ~~deemed reasonably certain of exercise.~~as applicable. The contractual maturities of lease liabilities were as follows:


Period Ending December 31,	Period Ending December 31,	Operating Leases		Finance Leases		Period Ending December 31,	Operating Leases		Finance Leases
		(Dollars in millions)					(Dollars in millions)
2021		$	17.5	$	5.6
2022	2022	18.6		7.1		2022	$	13.7	$	8.7
2023	2023	16.7		1.6		2023	17.6		6.0
2024	2024	6.0		0.7		2024	6.3		5.1
2025	2025	3.4		0.5		2025	3.6		4.9
2026 and thereafter		3.8		7.7
2026						2026	3.6		2.5
2027 and thereafter						2027 and thereafter	0.8		7.2
Total lease payments	Total lease payments	66.0		23.2		Total lease payments	45.6		34.4
Less imputed interest	Less imputed interest	(7.4)		(5.9)		Less imputed interest	(4.9)		(6.8)
Total lease liabilities	Total lease liabilities	$	58.6	$	17.3	Total lease liabilities	$	40.7	$	27.6

(10) Income Taxes

The Company's effective tax rate before remeasurement for the three months ended March 31, ~~2021~~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’s income tax benefit of ~~$1.8~~$1.0 million and ~~income tax provision of $3.0~~$1.8 million for the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, respectively, included a tax ~~benefits~~provision of $1.6 million and a tax benefit of $0.2 ~~million and $3.3~~ million, respectively, related to the remeasurement of foreign income tax accounts.

As described in Note 11. “Long-term Debt,” the Company completed the Refinancing Transactions (as defined below), 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 will recognize CODI from the Refinancing Transactions of approximately $60 million, and the income will be offset by the Company’s operating losses.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

(11) Long-term Debt

The Company’s total funded indebtedness (Indebtedness) as of March 31, ~~2021~~2022 and December 31, ~~2020~~2021 consisted of the following:


Debt Instrument (defined below, as applicable)	Debt Instrument (defined below, as applicable)	March 31, 2021		December 31, 2020		Debt Instrument (defined below, as applicable)	March 31, 2022		December 31, 2021
		(Dollars in millions)					(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes)	6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	60.3	$	459.0	6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	—	$	23.1
8.500% Senior Secured Notes due December 2024 (Peabody Notes)		172.7		0
10.000% Senior Secured Notes due December 2024 (Co-Issuer Notes)		193.9		0
8.500% Senior Secured Notes due December 2024 (2024 Peabody Notes)						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)						10.000% Senior Secured Notes due December 2024 (2024 Co-Issuer Notes)	193.6		193.9
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)						Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	188.8		206.0
6.375% Senior Secured Notes due March 2025 (2025 Notes)	6.375% Senior Secured Notes due March 2025 (2025 Notes)	500.0		500.0		6.375% Senior Secured Notes due March 2025 (2025 Notes)	77.5		334.9
Senior Secured Term Loan due 2024 (Co-Issuer Term Loan)		206.0		0
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	387.3		388.2		Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	321.8		322.8
Revolving credit facility		0		216.0
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)						3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	320.0		—

Finance lease obligations	Finance lease obligations	17.3		27.3		Finance lease obligations	27.6		29.3
Less: Debt issuance costs	Less: Debt issuance costs	(56.8)		(42.7)		Less: Debt issuance costs	(31.2)		(34.8)
		1,480.7		1,547.8			1,098.1		1,137.8
Less: Current portion of long-term debt	Less: Current portion of long-term debt	69.4		44.9		Less: Current portion of long-term debt	19.1		59.6
Long-term debt	Long-term debt	$	1,411.3	$	1,502.9	Long-term debt	$	1,079.0	$	1,078.2

~~Refinancing Transactions~~2021 Financing Activity

~~On January 29,~~During the first quarter of 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~~These 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~~a related 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 three months ended March 31, 2021. Following the settlement of the Exchange Offer, approximately $60.3 million aggregate principal amount of the 2022 Notes remain outstanding and are governed by the existing senior notes’ indenture (the Existing Indenture), as amended by the supplemental indenture described below.

Concurrently with the Exchange Offer, the Company solicited consents from holders of the 2022 Notes to certain proposed amendments to its 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.providers.

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Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

~~In connection with~~Subsequent to these transactions in the ~~Refinancing Transactions,~~first quarter of 2021, the Company ~~restructured~~completed additional financing transactions during 2021 intended to improve its capital structure. Such transactions included the ~~revolving loans under its existing credit agreement (the Credit Agreement) by (i) making a pay down~~implementation of ~~revolving loans thereunder in~~an at-the-market equity offering program pursuant to which the ~~aggregate~~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 ~~$10.0~~existing debt through various open market purchases at an aggregate cost of $232.4 million, ~~(ii)~~and the ~~Co-Issuers incurring $206.0~~issuance of an aggregate 10.0 million shares of ~~term loans under a credit agreement, dated as~~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 allowable open market purchases of its debt, the terms of the ~~Settlement Date (Co-Issuer Term Loans, Co-Issuer Term Loan Agreement), (iii)~~2024 Peabody Notes and the ~~Company entering into a~~ letter of credit facility ~~(the~~entered into by the Company in connection with the 2021 financing activity (Company LC Agreement) require the Company to make a mandatory repurchase offer 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 94.940% of their aggregate accreted value, plus accrued and unpaid interest, and a concurrent repurchase offer of priority lien obligations under the Company LC ~~Agreement)~~Agreement. The offer resulted in the valid tender and ~~(iv) amending~~purchase of $0.1 million aggregate accreted value of 2024 Peabody Notes and $30.0 million aggregate principal and commitment amounts under the ~~Credit~~Company LC Agreement ~~(collectively,~~during the ~~Revolver Transactions).~~

~~Co-Issuer Notes~~

three months ended March 31, 2022. The ~~terms~~Company’s purchase of the ~~Co-Issuer Notes are governed by an indenture, as amended~~principal and ~~restated as of February 3, 2021, by and among the Co-Issuers, Wilmington Trust, National Association, as trustee, and, on a limited basis,~~commitment amounts under the Company ~~(Co-Issuer Notes Indenture).~~

~~The Co-Issuer Notes mature on December 31, 2024~~LC Agreement was effected by the posting of $28.5 million of collateral with the administrative agent 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~~did not reduce the ~~terms of~~availability under the ~~notes. Beginning March 31, 2021, interest is payable on March 31, June 30, September 30 and December 31 of each year.~~facility. During the three months ended March 31, ~~2021,~~2022, the Company ~~recorded interest expense~~made no other open market purchases of ~~$3.6 million related to~~its debt.

The 2024 Co-Issuer Notes and the Co-Issuer ~~Notes.~~

~~The Co-Issuer Notes~~Term Loans are also subject to ~~amortization~~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)~~indenture) generated by the Wilpinjong Mine during each such period will be applied to the principal of ~~the Co-Issuer Notes~~such notes and ~~the Co-Issuer Term Loans~~loans on a pro rata basis, provided that the liquidity attributable to the ~~Co-Issuers~~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.

The ~~Co-Issuer~~2021 financing activity and related agreements are more fully described in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, as filed with the U.S. Securities and Exchange Commission on February 18, 2022.

3.250% Convertible Senior Notes ~~Indenture~~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 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 redemption of existing notes was deemed a debt extinguishment for accounting purposes. 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. During the three months ended March 31, 2022, the Company incurred interest expense of $1.0 million related to the 2028 Convertible Notes.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The 2028 Convertible Notes will be convertible at the option of the holders only in the following circumstances: (1) during any calendar quarter commencing after the calendar quarter ending on 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 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.

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.

Margin Financing Arrangement

The Revolving Facility is intended to support the Company’s 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 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 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 equity offering agreement limit was reached as a result of these issuances and may not be further utilized without amendment and approval by the sales agent. The Company had no outstanding borrowings and no availability under the Revolving Facility at March 31, 2022.

Table of Contents

PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The Credit Agreement contains customary covenants that, among other things, limit the ~~Co-Issuers’~~Company’s and ~~their~~its subsidiaries’ ability to incur additional ~~Indebtedness,~~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.~~assets.

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 lienBorrowings 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 modification 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 months ended March 31, 2021, the Company recorded interest expense of $3.1 million related to the Peabody Notes, which included approximately $0.8 million of in-kind interest.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

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 “Gain on early debt extinguishment.” 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~~Revolving Facility are unconditionally guaranteed, jointly and severally, on a senior ~~secured~~unsecured basis by substantially all of the ~~Peabody Guarantors (as defined below) on the Peabody Collateral (as defined below)~~Company’s material domestic subsidiaries (excluding any unrestricted subsidiaries). ~~The obligations are secured on a~~ ~~pari passu~~ ~~basis by the same collateral that secures the 6.375% senior secured notes due 2025 (the 2025 Notes), the Credit Agreement and~~

Retirement of 2022 Notes

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

~~Co-Issuer Term Loans~~Interest Charges

The ~~Co-Issuer Term Loans mature on December 31, 2024~~Company incurred total interest expense of $39.4 million and ~~bear interest at a rate of 10.00% per annum. The Company paid aggregate debt issuance costs of $7.1~~$52.4 million ~~that are being amortized over its term. During~~during the three months ended March 31, 2022 and 2021, respectively. These amounts included $13.5 million and $10.9 million, respectively, related to financial assurance instruments such as surety bonds and letters of credit, with the ~~Company recorded interest expense of $3.7 million~~remainder primarily related to the ~~Co-Issuer Term Loans.~~Company’s funded debt.

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 bearOf total interest ~~at 6.00% per annum and unused commitments are subject to a 0.50% per annum commitment fee. During~~expense incurred during the three months ended March 31, 2022 and 2021, ~~the Company recorded interest expense~~$3.8 million and ~~fees~~$4.9 million, respectively, was comprised of ~~$4.1 million~~non-cash charges primarily related to the amortization of debt issuance costs.

Cash payments for interest amounted to $37.2 million and $56.3 million during the three months ended March 31, 2022 and 2021, respectively.

The Senior Secured Term Loan is the Company’s only outstanding variable rate debt, which bore interest at LIBOR plus 2.75% per annum at March 31, 2022.

Covenant Compliance

The Company ~~LC Agreement.~~

~~In connection~~was compliant with all relevant covenants under its debt agreements at March 31, 2022, including the ~~Revolver Transactions, the Company amended its Credit Agreement to make certain changes in consideration of~~minimum aggregate liquidity requirement under 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~~which requires ~~that~~ the Company’s restricted subsidiaries to 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 will be 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.

Under the Company LC Agreement, the Company is permitted to effectuate 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 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.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

~~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.

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. During the three months ended March 31, 2021 and 2020, the Company recorded interest expense of $9.2 million and $9.1 million, respectively, related to the 2025 Notes.

On August 9, 2018, the Company executed an amendment to the Existing Indenture following the solicitation of consents from the requisite majority of holders of the 2025 Notes. The amendment permits a category of restricted payments at any time not to exceed the sum of $650.0 million, plus an additional $150.0 million per calendar year, commencing with calendar year 2019, with unused amounts in any calendar year carrying forward to and available for restricted payments in any subsequent calendar year. The Company paid consent fees to 2025 Note holders which amounted to $14.9 million. Such consent fees were capitalized as additional debt issuance costs to be amortized over the term of 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.

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 March 31, 2021 the Senior Secured Term Loan had a balance of $387.3 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. During the three months ended March 31, 2021 and 2020, the Company recorded interest expense of $3.3 million and $4.9 million, respectively, related to the Senior Secured Term Loan, which bore interest at LIBOR plus 2.75% per annum as of March 31, 2021.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

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 no revolving commitments or revolving loans under the Credit Agreement. Further, all 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 March 31, 2021. During the three months ended March 31, 2021 and 2020, the Company recorded interest expense and fees of $1.4 million and $1.7 million, respectively, related to the revolving loan facility.

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 at March 31, 2021.~~

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.

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

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


		Three Months Ended March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions)						(Dollars in millions)

Interest cost on projected benefit obligation	Interest cost on projected benefit obligation		$	5.1	$	7.0	Interest cost on projected benefit obligation		$	5.3	$	5.1
Expected return on plan assets	Expected return on plan assets		(5.7)		(7.4)		Expected return on plan assets		(5.9)		(5.7)

Net periodic pension benefit			$	(0.6)	$	(0.4)
Net periodic pension credit							Net periodic pension credit		$	(0.6)	$	(0.6)

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 March 31, ~~2021,~~2022, the Company’s qualified plans were expected to be at or above the Pension Protection Act thresholds. Minimum funding standards are legislated by the Employee Retirement Income Security Act of 1974 and are modified by pension funding stabilization provisions included in the Moving Ahead for Progress in the 21st Century Act of 2012, the Highway and Transportation Funding Act of 2014, the Bipartisan Budget Act of 2015 and the American Rescue Plan Act of 2021. 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., a wholly owned subsidiary of the Company, entered into a commitment agreement relating to the Peabody Investments Corp. Retirement Plan (the Plan) with The Prudential Insurance Company of America (Prudential) and Fiduciary Counselors Inc., as independent fiduciary to the Plan. Under the commitment agreement, the Plan purchased a group annuity contract (Group Annuity Contract) from Prudential for approximately $500 million and Prudential 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 Prudential for the payment of all benefits covered by the Group Annuity Contract. The purchase of the Group Annuity Contract was funded directly by the Plan’s assets. There will be no impact on the monthly retirement benefits paid to Plan participants. In addition, there will be no material impact on discretionary contributions for the Plan in 2022 or on the Company’s earnings in 2022 as a result of this transaction.

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

Three Months Ended March 31,
2021 2020
(Dollars in millions)
Service cost for benefits earned $ 0.2 $ 1.1
Interest cost on accumulated postretirement benefit obligation 2.9 5.5
Expected return on plan assets (0.2) (0.4)
Amortization of prior service credit (11.0) (2.2)
Net periodic postretirement benefit (benefit) cost $ (8.1) $ 4.0

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Service cost for benefits earned		$	0.2	$	0.2
Interest cost on accumulated postretirement benefit obligation		1.7		2.9
Expected return on plan assets		(0.2)		(0.2)
Amortization of prior service credit		(13.4)		(11.0)

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

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~~a Voluntary Employees Beneficiary Association (VEBA) ~~trusts~~trust 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~~trust in ~~2021~~2022 and plans to utilize a portion of VEBA assets to make certain benefit payments.

(13) Accumulated Other Comprehensive Income

The following table sets forth the after-tax components of accumulated other comprehensive income and changes thereto recorded during the three months ended March 31, ~~2021:~~2022:


		Foreign Currency Translation Adjustment		Prior Service Credit Associated with Postretirement Plans			Total Accumulated Other Comprehensive Income			Foreign Currency Translation Adjustment		Prior Service Credit Associated with Postretirement Plans		Total Accumulated Other Comprehensive Income
		(Dollars in millions)				(Dollars in millions)
December 31, 2020		$	1.8	$	204.0		$	205.8
December 31, 2021									December 31, 2021	$	0.8	$	297.1	$	297.9

Reclassification from other comprehensive income to earnings	Reclassification from other comprehensive income to earnings	0		(11.0)			(11.0)		Reclassification from other comprehensive income to earnings	—		(13.4)		(13.4)
Current period change	Current period change	(0.2)		0			(0.2)		Current period change	1.9		—		1.9
March 31, 2021		$	1.6	$	193.0		$	194.6
March 31, 2022									March 31, 2022	$	2.7	$	283.7	$	286.4

Postretirement health care and life insurance benefits reclassified from other comprehensive income to earnings of $13.4 million a~~$11.0~~nd $11.0 million ~~and~~ ~~$2.2 million~~ during the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, respectively, are included in “Net periodic benefit ~~(credit) costs,~~credit, excluding service cost” in the unaudited condensed consolidated statements of operations.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(14) ~~Other Events~~

~~Cost Repositioning Program~~

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 $2.1 million and $6.5 million for the three months ended March 31, 2021 and 2020, respectively, and were associated with both involuntary and voluntary workforce reductions.

The Shoal Creek Mine remains idled as the Company continues activities to increase productivity, lower costs and improve yields from the operation in the future. The restart of mine production and coal shipments is contingent upon successful completion of these initiatives and stable customer demand. Included in the initiatives is a preparation plant upgrade project, which is anticipated to be commissioned by the middle of the third quarter of 2021. Additionally, the Shoal Creek labor contract expired on April 1, 2021 and negotiations with the workforce are ongoing.

While discussions are ongoing with customers and workforce, the Metropolitan Mine full workforce returned to the mine in early May. Development work at the mine has been ongoing through the idle period and longwall production is anticipated to restart in the second quarter of 2021, with ramp up to full production in the third quarter of 2021.

~~(15)~~ 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 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.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

For all but ~~the~~ 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 ~~the~~ 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). Since the 2028 Convertible Notes were issued on March 1, 2022, there were approximately 5.5 million shares of potentially dilutive common stock for the three months ended March 31, 2022. These potentially dilutive shares were excluded from the computation of diluted EPS for the three months ended March 31, 2022, because to do so would have been anti-dilutive as the Company reported a net loss from continuing operations during the period. 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 approximately ~~1.3~~1.2 million and ~~3.0~~1.3 million for the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, 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.

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


		Three Months Ended March 31,			Three Months Ended March 31,
			2021			2020			2022		2021
			(In millions, except per share data)						(In millions, except per share data)
EPS numerator:	EPS numerator:							EPS numerator:
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		$	(77.7)		$	(129.3)	Loss from continuing operations, net of income taxes	$	(119.8)	$	(77.7)
Less: Net income (loss) attributable to noncontrolling interests			0.4			(1.8)
Less: Net (loss) income attributable to noncontrolling interests								Less: Net (loss) income attributable to noncontrolling interests	(1.1)		0.4
Loss from continuing operations attributable to common stockholders	Loss from continuing operations attributable to common stockholders		(78.1)			(127.5)		Loss from continuing operations attributable to common stockholders	(118.7)		(78.1)

Loss from discontinued operations, net of income taxes	Loss from discontinued operations, net of income taxes		(2.0)			(2.2)		Loss from discontinued operations, net of income taxes	(0.8)		(2.0)

Net loss attributable to common stockholders	Net loss attributable to common stockholders		$	(80.1)		$	(129.7)	Net loss attributable to common stockholders	$	(119.5)	$	(80.1)

EPS denominator:	EPS denominator:							EPS denominator:

Weighted average shares outstanding — basic and diluted	Weighted average shares outstanding — basic and diluted		98.4			97.2		Weighted average shares outstanding — basic and diluted	136.2		98.4

Basic and diluted EPS attributable to common stockholders:	Basic and diluted EPS attributable to common stockholders:							Basic and diluted EPS attributable to common stockholders:
Loss from continuing operations	Loss from continuing operations		$	(0.79)		$	(1.31)	Loss from continuing operations	$	(0.87)	$	(0.79)
Loss from discontinued operations	Loss from discontinued operations		(0.02)			(0.02)		Loss from discontinued operations	(0.01)		(0.02)
Net loss attributable to common stockholders	Net loss attributable to common stockholders		$	(0.81)		$	(1.33)	Net loss attributable to common stockholders	$	(0.88)	$	(0.81)

~~(16)~~

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(15) Financial Instruments and Other Guarantees

~~In the normal course of business, the~~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 March 31, ~~2021,~~2022, such instruments included ~~$1,570.8~~$1,484.9 million of surety bonds and ~~$423.4~~$469.1 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. 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.

In ~~connection~~November 2020, the Company entered into a surety agreement with the ~~Refinancing Transactions described~~providers of its surety bond portfolio to resolve previous collateral demands. In accordance with the surety agreement, the Company initially provided $75.0 million of collateral, in ~~Note 11. “Long-term Debt,” at~~ the ~~Settlement Date, all~~form of letters of ~~credit issued under~~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 ~~former revolving credit facility were deemed issued under~~free cash flow for the ~~Company LC Agreement~~year ended December 31, 2021, additional collateral of $13.0 million was posted in ~~support~~January 2022 in the form of letters of credit. No such additional collateral was required for the ~~same obligations.~~period ended March 31, 2022.

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.

At March 31, ~~2021,~~2022, the Company’s asset retirement obligations of ~~$735.9~~$724.5 million were supported by surety bonds of ~~$1,394.5~~$1,312.1 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 March 31, ~~2021~~2022 which served as collateral for surety bonds in support of asset retirement obligations amounted to ~~$297.7~~$340.0 million.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

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 March 31, ~~2021,~~2022, the Company had 0no outstanding borrowings and ~~$120.8~~$161.8 million of letters of credit issued under the Securitization Program. The letters of credit were primarily in support of ~~portions of the Company’s obligations for property and casualty insurance.~~reclamation obligations. Availability under the Securitization Program, which is adjusted for certain ineligible receivables, was ~~$0.8~~$1.6 million at March 31, ~~2021.~~2022. The Company ~~had $43.5 million of~~was required to post cash collateral ~~posted~~ under the Securitization Program of $24.7 million at March 31, ~~2021~~2022 and none at December 31, ~~2020~~2021..

The Company incurred interest and fees associated with the Securitization Program of $0.9 million and $0.7 million during the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, respectively, which have been recorded as “Interest expense” in the accompanying unaudited condensed consolidated statements of operations.

~~Cash Collateral Arrangements and Restricted Cash~~24

~~From time to time,~~

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Collateralized Letter of Credit Agreement

In February 2022, the Company ~~is required~~entered into a new agreement, which provides up to ~~remit cash to certain regulatory authorities and other third parties as collateral~~$250.0 million of capacity for ~~financial assurances associated with a variety~~irrevocable standby letters of ~~long-term obligations and commitments surrounding employee related matters and the mining,~~credit in support of reclamation ~~and shipping of its production. At March 31, 2021,~~bonding. The agreement requires the Company ~~had $43.5~~to provide cash collateral at a level of 103% of the aggregate amount of letters of credit outstanding under the arrangement (limited to $5.0 million total excess collateralization.) Outstanding letters of credit bear a fixed fee in the amount of 0.75% per annum. The Company receives a deposit rate of 0.35% per annum on the amount of cash collateral ~~and restricted cash requirements due to outstanding~~posted in support of letters of credit, ~~temporarily exceeding~~with the ~~balance~~rate subject to increases over time. The agreement has an initial expiration date of ~~eligible receivables at quarter-end.~~December 31, 2025. The Company ~~had 0 such requirements at~~ ~~December~~did not utilize the collateralized letter of credit facility until subsequent to March 31, ~~2020~~.

~~Other~~

Substantially all of the Company’s U.S. subsidiaries provide financial guarantees under long-term debt agreements entered into by the Company. The maximum amounts payable under the Company’s debt agreements are equal to the respective principal and interest payments.2022.

~~(17)~~(16) Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of March 31, ~~2021,~~2022, purchase commitments for capital expenditures were ~~$46.0~~$43.9 million, all of which is obligated within the next ~~four~~three years, with ~~$38.4~~$35.6 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.

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

Litigation 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 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 ~~and~~while the Plaintiffs’ response letter ~~is due~~was filed on May 6, 2021. The defendants ~~must file~~filed their motion to dismiss byon June 7, 2021. ~~Additional briefings~~The Plaintiffs’ opposition brief to the motion to dismiss was filed on July 22, 2021. The defendants filed their reply to Plaintiff’s opposition on August 23, 2021, completing briefing at this phase of ~~litigation should be completed by~~ the ~~end~~litigation. On March 7, 2022, the Court granted in part and denied in part the defendants’ motion to dismiss. As a result of ~~August 2021.~~this decision, only Plaintiffs’ allegations relating to the Company’s September 25, 2018 statements remain in the case. The Company believes the lawsuit lacks merit and intends to vigorously defend against the allegations.

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 ~~United States~~U.S. District Court for the District of Delaware against certain directors and a former ~~officer~~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.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 ~~United States~~U.S. District Court for the District of Delaware against the directors ~~two~~and current ~~officers~~ and a former ~~officer~~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 ~~United States District~~ Court ~~for the District of Delaware~~ ~~ruled~~rules on the motion to dismiss in the Securities Class Action. In light of the March 7, 2022 decision on the motion to dismiss in the Securities Class Action, the parties are discussing how to proceed with the derivative actions, which currently remained stayed. The Company also believes that the derivative actions lack merit and ~~intended~~intends to vigorously defend against the allegations.

~~Litigation Relating to Continuing Operations~~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.

~~(18)~~(17) 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 our Chief Executive Officer, uses Adjusted EBITDA as the primary metric to measure the segments’ operating ~~performance.~~

~~Table of Contents~~

~~PEABODY ENERGY CORPORATION~~

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

performance and allocate resources.

Adjusted EBITDA is a non-GAAP financial measure defined as 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 March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions)						(Dollars in millions)
Revenues:
Revenue:							Revenue:
Seaborne Thermal Mining	Seaborne Thermal Mining		$	176.4	$	201.1	Seaborne Thermal Mining		$	251.2	$	176.4
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		87.5		193.2		Seaborne Metallurgical Mining		321.3		87.5
Powder River Basin Mining	Powder River Basin Mining		228.4		266.6		Powder River Basin Mining		251.2		228.4
Other U.S. Thermal Mining	Other U.S. Thermal Mining		149.3		192.3		Other U.S. Thermal Mining		203.1		149.3
Corporate and Other	Corporate and Other		9.7		(7.0)		Corporate and Other		(335.4)		9.7
Total	Total		$	651.3	$	846.2	Total		$	691.4	$	651.3

Adjusted EBITDA:	Adjusted EBITDA:						Adjusted EBITDA:
Seaborne Thermal Mining	Seaborne Thermal Mining		$	28.5	$	55.1	Seaborne Thermal Mining		$	90.5	$	28.5
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		(22.4)		(32.7)		Seaborne Metallurgical Mining		181.0		(22.4)
Powder River Basin Mining	Powder River Basin Mining		30.1		25.4		Powder River Basin Mining		7.6		30.1
Other U.S. Thermal Mining	Other U.S. Thermal Mining		36.2		38.5		Other U.S. Thermal Mining		50.0		36.2
Corporate and Other	Corporate and Other		(11.3)		(49.5)		Corporate and Other		(1.6)		(11.3)
Total	Total		$	61.1	$	36.8	Total		$	327.5	$	61.1

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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


		Three Months Ended March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions)						(Dollars in millions)
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		$	(77.7)	$	(129.3)	Loss from continuing operations, net of income taxes		$	(119.8)	$	(77.7)
Depreciation, depletion and amortization	Depreciation, depletion and amortization		68.3		106.0		Depreciation, depletion and amortization		72.9		68.3
Asset retirement obligation expenses	Asset retirement obligation expenses		15.9		17.6		Asset retirement obligation expenses		15.0		15.9
Restructuring charges	Restructuring charges		2.1		6.5		Restructuring charges		1.6		2.1
Transaction costs related to joint ventures			0		4.2

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		(1.5)		(0.7)		Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates		(0.6)		(1.5)
Interest expense	Interest expense		52.4		33.1		Interest expense		39.4		52.4
Gain on early debt extinguishment			(3.5)		0
Net loss (gain) on early debt extinguishment							Net loss (gain) on early debt extinguishment		23.5		(3.5)
Interest income	Interest income		(1.5)		(3.1)		Interest income		(0.5)		(1.5)

Unrealized losses on economic hedges			1.9		2.2
Unrealized losses (gains) on non-coal trading derivative contracts			7.6		(0.1)
Unrealized losses on derivative contracts related to forecasted sales							Unrealized losses on derivative contracts related to forecasted sales		301.0		1.9
Unrealized (gains) losses on foreign currency option contracts							Unrealized (gains) losses on foreign currency option contracts		(3.3)		7.6

Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition		(1.1)		(2.6)		Take-or-pay contract-based intangible recognition		(0.7)		(1.1)
Income tax (benefit) provision			(1.8)		3.0
Income tax benefit							Income tax benefit		(1.0)		(1.8)
Adjusted EBITDA	Adjusted EBITDA		$	61.1	$	36.8	Adjusted EBITDA		$	327.5	$	61.1

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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, including, without limitation, the section captioned “Outlook” in this Item 2.~~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. ~~Factors that could affect its results or an investment in its 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 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;

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

•the Company faces numerous uncertainties in estimating its economically recoverable coal reserves and inaccuracies in its estimates could result in lower than expected revenues, 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 coronavirus (COVID-19) pandemic 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 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;

•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 payment of dividends on Peabody’s stock or repurchase 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 and in “Risk Factors,” set forth in Part II, Item 1A of this Quarterly Report on Form 10-Q.

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.

~~Table of Contents~~

~~Overview~~

Peabody is a leading coal producer. In 2020, the Company produced and sold 128.8 million and 132.6 million tons of coal, respectively, from continuing operations. At March 31, 2021, 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. “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.

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. As further described in the “Results of Operations” section contained within this Item 2, the Company incurred restructuring charges of $2.1 million and $6.5 million during the three months ended March 31, 2021 and 2020, respectively, related to workforce reductions made across the organization through the use of both involuntary and voluntary reductions.

~~Results of Operations~~

Non-GAAP Financial Measures

The following discussion of the Company’s results of operations includes references to and analysis of Adjusted EBITDA, which is a financial measure 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.~~performance and allocate resources.

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.

2928

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~~Three Months Ended~~Overview

Peabody is a leading producer of metallurgical and thermal coal. In 2021, the Company produced and sold 126.9 million and 130.1 million tons of coal, respectively, from continuing operations. At March 31,~~2021 Compared~~ 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 17. “Segment Information” to the ~~Three Months Ended March 31,2020~~

~~Summary~~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 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 March 31, ~~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 March 31, ~~2021~~2022 due to quality differentials and the majority 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. 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 March 31, ~~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		March 31, 2021			High		Low		Average		March 31, 2022		April 29, 2022
Premium HCC (1)	Premium HCC (1)	$	158.70	$	99.50	$	127.57	$	112.80	Premium HCC (1)	$	670.50	$	357.75	$	487.80	$	515.00	$	518.00
Premium PCI coal (1)	Premium PCI coal (1)	110.50		91.50		103.22		110.50		Premium PCI coal (1)	655.00		244.50		393.47		475.50		460.00
Newcastle index thermal coal (1)	Newcastle index thermal coal (1)	103.95		80.78		88.50		100.59		Newcastle index thermal coal (1)	395.59		201.54		263.75		271.06		356.03
API 5 thermal coal (1)	API 5 thermal coal (1)	59.32		50.75		54.65		56.00		API 5 thermal coal (1)	284.20		109.66		172.41		190.00		196.62
PRB 8,800 Btu/Lb coal (2)	PRB 8,800 Btu/Lb coal (2)	11.95		11.85		11.91		11.95		PRB 8,800 Btu/Lb coal (2)	27.50		17.50		21.67		17.50		15.78
Illinois Basin 11,500 Btu/Lb coal (2)	Illinois Basin 11,500 Btu/Lb coal (2)	32.00		29.75		30.96		32.00		Illinois Basin 11,500 Btu/Lb coal (2)	155.00		88.00		104.06		126.00		131.00

(1) Prices expressed per metric tonne.

(2) Prices expressed per short ton.

Within the global coal industry, supply and demand ~~disruptions~~for its products and the supplies used for mining have been ~~widespread as~~impacted by the recent Russian-Ukrainian conflict and the coronavirus (COVID-19) pandemic. Furthermore, inflationary pressures have contributed to rising costs. As future developments related to the Russian-Ukrainian conflict, the COVID-19 pandemic ~~has 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 three months ended March 31, ~~2021~~2022 presented herein may not be indicative of ~~the~~their ultimate ~~impacts~~impacts.

Table of ~~the COVID-19 pandemic given the various levels of response and unknown duration, and the potential for continued weak demand for the Company’s products.~~Contents

Within the seaborne metallurgical coal market, the ~~imbalance between Australian export~~three months ended March 31, 2022 were characterized by significant volatility, primarily driven by sanctions and ~~Chinese delivered~~trade redistribution efforts following the onset of the Russian-Ukrainian conflict. Buyers in Atlantic markets are seeking to mitigate exposure to Russian coal imports, causing an upswell in demand for supply from other regions such as Australia, the U.S. and Canada. Market prices ~~remains wide, with~~rose approximately $300 per metric tonne from January to mid-March, far exceeding prior records, before falling a similar quantum through the ~~delivered price into China trading at roughly double those seen free~~end of March and start of April amid scant market liquidity. Prices have once more begun increasing in April, following the European Union and Japan firming their stance and announcing total bans on ~~board Australia as~~Russian coal imports. This will have a particular impact on the PCI market, where Russia accounts for approximately 35% of global traded volumes. China’s unofficial ban on Australian ~~coals~~coal remains in ~~place. In addition, increased COVID-19 concerns~~place and continues to disrupt traditional trade flows. Global supply remains tight and this dynamic is only intensifying with the sanctions imposed on Russian imports. The Company believes energy shortages in ~~India are further weighing on Australian hard coking coal pricing. These factors continue~~some markets present a risk to ~~pressure~~industrial activity but the ~~seaborne metallurgical coal~~underlying market ~~despite global steel production increasing 5% year-over-year.~~

In contrast, the spread between Australian hard coking coal pricing and low-vol PCI has recently narrowed to near parity. Tight low-vol PCI supply, coupled with China paying a premium for Russian coals, have contributed to rising low-vol PCI prices.fundamentals remain constructive.

Within the seaborne thermal coal market, the Russian-Ukrainian conflict and the subsequent ban of Russian coal by European countries has driven global thermal coal prices to record levels and high volatility during the three months ended March 31, 2022. Prior to the Russian-Ukrainian conflict, thermal coal supply was already tight ~~supplies~~due to an export ban in Indonesia in January as well as heavy rains and ~~low inventory levels have kept~~COVID-19 restrictions in Australia. During the three months ended March 31, 2022, Newcastle thermal coal pricing ~~at improved~~hit record levels ~~year-to-date. China’s~~due to concerns over a severe supply shock following the onset of the Russian-Ukrainian conflict, but pricing subsided slightly to end the quarter in the $200 per metric tonne range. In China, domestic coal production has been strong during the three months ended March 31, 2022, which has lowered import demand to start the year. In India, coal production has been elevated as well, allowing coal buyers to wait for lower thermal seaborne prices and limit imports; however stockpile levels have fallen recently. Overall, global thermal coal markets remain turbulent as supply remains ~~hampered~~tight and European coal importers look to replace Russian coal.

In the United States, overall electricity demand increased more than 3% year-over-year, positively impacted by ~~heightened safety inspections. In addition, India’s~~weather. Through the three months ended March 31, 2022, electricity generation from thermal coal ~~stockpiles~~has declined year-over-year due to strong year-over-year comparatives in February 2021, as well as record renewable generation. Coal’s share of electricity generation has declined slightly to approximately 22% for the three months ended March 31, 2022, while wind generation’s share has increased to 11%. Coal inventories have ~~been falling gradually~~continued to decline since ~~mid-December as government-owned plants have reduced intake~~December 2021, with a decline of approximately 5% or 5 million tons. During the three months ended March 31, 2022, utility consumption of PRB coal rose approximately 1% compared to the prior year period.

Financing and ~~there~~Liquidity Transactions

During the first quarter of 2022, Peabody issued convertible senior unsecured notes and used the proceeds of the offering to retire nearer term higher cost senior secured debt. This both lowered the Company’s borrowing rates and extended debt maturities to 2028.

High demand and tight supply for coal globally 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. As a ~~delay~~result, Peabody posted additional cash margin of $351.6 million during the three months ended March 31, 2022 to satisfy the margin requirements for its derivative contracts.

During the quarter, the Company put in ~~typical restocking ahead~~place a revolving financing facility to support near-term liquidity requirements, particularly with respect to these cash margin requirements which fluctuate depending upon the underlying market coal prices. The Company received proceeds under the revolving financing facility which were repaid in full with proceeds from the sale of shares under the ~~monsoon season~~at-the-market offering program.

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

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 ~~June. As~~the U.S., for utility-scale photovoltaic solar generation and battery storage. The Company’s interest in R3 is accounted for as an equity method investment. The Company contributed $2.0 million to R3 and recorded an equity loss of $1.0 million from its operations during the ~~end of~~three months ended March ~~2021, India’s plant inventory levels were estimated at approximately 15 days burn versus 28 days a year ago.~~31, 2022.

Table of Contents

In March 2022, Peabody Investments Corp., a wholly owned subsidiary of the ~~United States, overall electricity demand increased 2% year-over-year, positively impacted~~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 ~~cold weather during~~ the ~~three months ended~~insurer for the payment of all benefits covered by the group annuity contract. Refer to Note 12. “Pension and Postretirement Benefit Costs” to the accompanying unaudited condensed consolidated financial statements for a further discussion of this transaction.

Results of Operations

Three Months Ended March 31, 2021. Electricity generation from thermal coal has increased by 37% year-over-year as a result of higher natural gas prices. This has positively impacted coal’s share of electricity generation, with a rise2022 Compared to ~~approximately 24%~~the Three Months Ended March 31,2021

Summary

The Company’s revenue for the three months ended March 31, 2021, while causing natural gas’s share to decline to approximately 34%. Stronger coal use has contributed to decreasing coal stockpile levels. Since December 2020, coal inventories have fallen by approximately 20 million tons. Through the three months ended March 31, 2021, utility consumption of PRB coal rose approximately 35% compared to the prior year period.

~~The Company’s revenues for the three months ended March 31, 2021 decreased~~2022 increased compared to the same ~~periods~~period in ~~2020~~2021 ($~~194.9~~40.1 million) primarily due to ~~lower~~the impacts of higher pricing, offset by net unrealized mark-to-market losses on derivative contracts related to forecasted sales ~~volumes~~ and ~~lower realized prices.~~other financial trading activity ($290.2 million).

Results from continuing operations, net of income taxes for the three months ended March 31, ~~2021 increased~~2022 decreased compared to the same period in the prior year ($~~51.6~~42.1 million) ~~as the result of lower~~, primarily due to higher operating costs and expenses ~~due largely~~($116.4 million) which reflected inflationary pressures and increased costs for materials, services, repairs and labor related to the ~~sales volume decline as well as production efficiencies~~Company’s efforts to ramp up the operations to meet current and ~~other cost improvements~~anticipated volumes. The results were further impacted by net losses on early debt extinguishments in the current year ($~~196.9 million) and lower depreciation, depletion and amortization ($37.7~~27.0 million). These ~~favorable~~unfavorable variances were offset by ~~the unfavorable~~improved results from equity affiliates ($45.6 million), a favorable revenue variance due to higher pricing exceeding the net unrealized mark-to-market losses as described above ($40.1 million); and ~~increased~~decreased interest expense ($~~19.3~~13.0 million) ~~primarily resulting from fees related to new debt arrangements entered into during the three months ended March 31, 2021.~~.

Adjusted EBITDA for the three months ended March 31, ~~2021~~2022 reflected a year-over-year increase of ~~$24.3~~$266.4 million.

As of March 31, ~~2021,~~2022, the Company’s available liquidity was approximately ~~$604~~$842 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	Decrease
		March 31,	to Volumes						Three Months Ended March 31,	(Decrease ) Increase to Volumes
			2021	2020	Tons	%					2022	2021	Tons	%
		(Tons in millions)							(Tons in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining		4.1	4.6	(0.5)	(11)	%	Seaborne Thermal Mining			3.8	4.1	(0.3)	(7)	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		1.0	2.0	(1.0)	(50)	%	Seaborne Metallurgical Mining			1.2	1.0	0.2	20	%
Powder River Basin Mining	Powder River Basin Mining		20.7	23.5	(2.8)	(12)	%	Powder River Basin Mining			20.6	20.7	(0.1)	—	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining		3.9	4.9	(1.0)	(20)	%	Other U.S. Thermal Mining			4.2	3.9	0.3	8	%
Total tons sold from mining segments	Total tons sold from mining segments		29.7	35.0	(5.3)	(15)	%	Total tons sold from mining segments			29.8	29.7	0.1	—	%
Corporate and Other	Corporate and Other		0.5	0.6	(0.1)	(17)	%	Corporate and Other			0.1	0.5	(0.4)	(80)	%
Total tons sold	Total tons sold		30.2	35.6	(5.4)	(15)	%	Total tons sold			29.9	30.2	(0.3)	(1)	%

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Supplemental Financial Data

The following table presents supplemental financial data by operating segment:


		Three Months Ended		(Decrease)									Three Months Ended March 31,	Increase (Decrease)
		March 31,		Increase										2022	2021	$		%
				2021		2020		$		%
Revenues per Ton - Mining Operations (1)
Revenue per Ton - Mining Operations (1)												Revenue per Ton - Mining Operations (1)
Seaborne Thermal	Seaborne Thermal			$	43.36	$	44.10	$	(0.74)	(2)	%	Seaborne Thermal				$	66.86	$	43.36	$	23.50	54	%
Seaborne Metallurgical	Seaborne Metallurgical			87.47		95.65		(8.18)		(9)	%	Seaborne Metallurgical				258.43		87.47		170.96		195	%
Powder River Basin	Powder River Basin			11.01		11.36		(0.35)		(3)	%	Powder River Basin				12.18		11.01		1.17		11	%
Other U.S. Thermal	Other U.S. Thermal			38.76		39.25		(0.49)		(1)	%	Other U.S. Thermal				48.46		38.76		9.70		25	%
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			$	36.36	$	32.03	$	4.33	14	%	Seaborne Thermal				$	42.77	$	36.36	$	6.41	18	%
Seaborne Metallurgical	Seaborne Metallurgical			109.89		111.82		(1.93)		(2)	%	Seaborne Metallurgical				112.87		109.89		2.98		3	%
Powder River Basin	Powder River Basin			9.56		10.28		(0.72)		(7)	%	Powder River Basin				11.81		9.56		2.25		24	%
Other U.S. Thermal	Other U.S. Thermal			29.37		31.39		(2.02)		(6)	%	Other U.S. Thermal				36.54		29.37		7.17		24	%
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			$	7.00	$	12.07	$	(5.07)	(42)	%	Seaborne Thermal				$	24.09	$	7.00	$	17.09	244	%
Seaborne Metallurgical	Seaborne Metallurgical			(22.42)		(16.17)		(6.25)		(39)	%	Seaborne Metallurgical				145.56		(22.42)		167.98		749	%
Powder River Basin	Powder River Basin			1.45		1.08		0.37		34	%	Powder River Basin				0.37		1.45		(1.08)		(74)	%
Other U.S. Thermal	Other U.S. Thermal			9.39		7.86		1.53		19	%	Other U.S. Thermal				11.92		9.39		2.53		27	%

(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	(Decrease) Increase
		March 31,	to Revenues									Three Months Ended March 31,	Increase (Decrease) to Revenue
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining		$	176.4	$	201.1	$	(24.7)	(12)	%	Seaborne Thermal Mining			$	251.2	$	176.4	$	74.8	42	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		87.5		193.2		(105.7)		(55)	%	Seaborne Metallurgical Mining			321.3		87.5		233.8		267	%
Powder River Basin Mining	Powder River Basin Mining		228.4		266.6		(38.2)		(14)	%	Powder River Basin Mining			251.2		228.4		22.8		10	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining		149.3		192.3		(43.0)		(22)	%	Other U.S. Thermal Mining			203.1		149.3		53.8		36	%
Corporate and Other	Corporate and Other		9.7		(7.0)		16.7		239	%	Corporate and Other			(335.4)		9.7		(345.1)		(3,558)	%
Revenues			$	651.3	$	846.2	$	(194.9)	(23)	%
Revenue											Revenue			$	691.4	$	651.3	$	40.1	6	%

Seaborne Thermal Mining. Segment ~~revenues decreased~~revenue increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year primarily due to favorable realized coal pricing ($110.9 million), offset by unfavorable volumes ($36.1 million) which were impacted by a longwall move at the Wambo Underground Mine, wet weather and COVID-19-related staffing shortages.

Seaborne Metallurgical Mining. Segment revenue increased during the three months ended March 31, 2022 compared to the same period in the prior year due to ~~unfavorable~~favorable realized coal pricing ($190.2 million) and favorable volume and mix variances ($~~18.6 million) and unfavorable realized coal pricing ($6.1~~43.6 million).

~~Seaborne Metallurgical~~Powder River Basin Mining. Segment ~~revenues decreased~~revenue increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year primarily due to ~~unfavorable volume and mix variances ($101.3 million) and unfavorable~~favorable realized coal pricing ($27.2 million), partially offset by unfavorable volumes ($4.4 million). The unfavorable volume variances resulted from the idling of the Shoal Creek and Metropolitan Mines during the fourth quarter of 2020, lower demand and the closure of the Millennium Mine during the second quarter of 2020.

Table of Contents

~~Powder River Basin~~Other U.S. Thermal Mining. Segment revenue increased during the three months ended March 31, 2022 compared to the same period in the prior year due to favorable realized pricing ($40.0 million) and favorable volumes ($13.8 million).

Corporate and Other. Segment ~~revenues~~revenue decreased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year primarily due to ~~lower demand~~net unrealized mark-to-market losses on derivative contracts related to forecasted coal sales and other financial trading activity ($~~31.6~~285.3 million) and ~~unfavorable realized coal pricing ($6.6 million).~~

~~Other U.S. Thermal Mining.~~ ~~Segment revenues decreased during the three months ended March 31, 2021 compared to the same period in the prior year primarily due to~~ lower ~~demand.~~

~~Corporate and Other.~~ ~~Segment revenues increased during the three months ended March 31, 2021 compared to the same period in the prior year primarily due to higher~~ results from trading ~~activities.~~activities ($61.8 million).

Adjusted EBITDA

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


		Three Months Ended	(Decrease) Increase
		March 31,	to Segment Adjusted EBITDA									Three Months Ended March 31,	Increase (Decrease) to Segment Adjusted EBITDA
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining		$	28.5	$	55.1	$	(26.6)	(48)	%	Seaborne Thermal Mining			$	90.5	$	28.5	$	62.0	218	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		(22.4)		(32.7)		10.3		31	%	Seaborne Metallurgical Mining			181.0		(22.4)		203.4		908	%
Powder River Basin Mining	Powder River Basin Mining		30.1		25.4		4.7		19	%	Powder River Basin Mining			7.6		30.1		(22.5)		(75)	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining		36.2		38.5		(2.3)		(6)	%	Other U.S. Thermal Mining			50.0		36.2		13.8		38	%
Corporate and Other	Corporate and Other		(11.3)		(49.5)		38.2		77	%	Corporate and Other			(1.6)		(11.3)		9.7		86	%
Adjusted EBITDA (1)	Adjusted EBITDA (1)		$	61.1	$	36.8	$	24.3	66	%	Adjusted EBITDA (1)			$	327.5	$	61.1	$	266.4	436	%

(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 ~~decreased~~increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year as a result of ~~unfavorable foreign currency impacts ($16.5 million), unfavorable volume variances ($14.6 million) and lower~~higher realized net coal pricing ($~~5.6~~102.3 million)~~. The decrease was~~, partially offset by ~~various cost improvements~~unfavorable operational costs ($~~7.5~~40.5 million). resulting from the longwall move at the Wambo Underground Mine, the impacts of wet weather, COVID-19-related staffing shortages and inflationary pressures.

Seaborne Metallurgical Mining. Segment Adjusted EBITDA increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year due to higher realized net coal pricing ($176.3 million) and cost improvements at certain mines ($~~18.6~~23.4 million) ~~and lower~~.

Powder River Basin Mining. Segment Adjusted EBITDA decreased during the three months ended March 31, 2022 compared to the same period in the prior year due to higher costs for materials, services, repairs and labor ($~~21.2~~29.5 million) ~~as a result of~~related to efforts to ramp up the ~~idling of the Metropolitan Mine during the fourth quarter of 2020~~operations to meet current and anticipated volumes and the ~~closure~~unfavorable impacts of ~~the Millennium Mine during the second quarter~~higher commodity pricing ($14.7 million), both of ~~2020. The increase was~~which were also impacted by inflationary pressures. These decreases were partially offset by ~~unfavorable foreign currency impacts~~higher realized net coal pricing ($~~28.2~~27.3 million).

~~Powder River Basin~~Other U.S. Thermal Mining. Segment Adjusted EBITDA increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year due to ~~lower~~higher realized net coal pricing ($41.6 million) and favorable volumes ($6.7 million). These increases were offset by higher costs for materials, services, repairs and labor ($~~7.4~~24.4 million) related to efforts to ramp up the operations to meet current and ~~favorable mine sequencing~~anticipated volumes and the unfavorable impacts ~~($3.8 million). The increase was partially offset by the impact~~ of ~~lower volumes ($4.9 million) and lower realized net coal~~higher commodity pricing ($~~3.8 million).~~

~~Other U.S. Thermal Mining.~~ ~~Segment Adjusted EBITDA decreased during the three months ended March 31, 2021 compared to the same period in the prior year due to unfavorable volume and mix variances ($21.5~~10.0 million), ~~offset~~both of which were also impacted by ~~lower costs for materials, services, repairs and labor ($21.3 million).~~inflationary pressures.

Table of Contents

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


		Three Months Ended	Increase (Decrease)
		March 31,	to Adjusted EBITDA									Three Months Ended March 31,	Increase (Decrease) to Adjusted EBITDA
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Middlemount (1)	Middlemount (1)		$	(2.3)	$	(9.7)	$	7.4	76	%	Middlemount (1)			$	45.1	$	(2.3)	$	47.4	2,061	%
Resource management activities (2)	Resource management activities (2)		0.4		8.0		(7.6)		(95)	%	Resource management activities (2)			3.5		0.4		3.1		775	%
Selling and administrative expenses	Selling and administrative expenses		(21.7)		(24.9)		3.2		13	%	Selling and administrative expenses			(23.1)		(21.7)		(1.4)		(6)	%
Other items, net (3)	Other items, net (3)		12.3		(22.9)		35.2		154	%	Other items, net (3)			(27.1)		12.3		(39.4)		(320)	%
Corporate and Other Adjusted EBITDA	Corporate and Other Adjusted EBITDA		$	(11.3)	$	(49.5)	$	38.2	77	%	Corporate and Other Adjusted EBITDA			$	(1.6)	$	(11.3)	$	9.7	86	%

(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 ~~$11.7~~$45.0 million and ~~$4.4~~$11.7 million during the three months ended March 31, ~~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 in~~ Corporate and Other Adjusted EBITDA benefited during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year was primarily driven by favorable trading results ($12.1 million); lower postretirement healthcare costs ($11.3 million) primarily due to changes made to one of the Company’s postretirement health care benefit plans during the third quarter of 2020;from a favorable variance in Middlemount’s results ($47.4 million) due to the ~~combined~~ impact of ~~improved production and cost improvements; lower containment and holding costs for the Company’s North Goonyella Mine ($6.1 million); and favorable corporate hedging~~higher sales pricing. This benefit was largely offset by unfavorable trading results ($~~5.7~~41.9 million). ~~These favorable results were partially offset by resource management gains recorded in the prior year period ($7.5 million).~~

~~Table of Contents~~

Loss From Continuing Operations, Net of Income Taxes

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


		Three Months Ended	Increase (Decrease)
		March 31,	to Income									Three Months Ended March 31,	Increase (Decrease) to Income
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Adjusted EBITDA (1)	Adjusted EBITDA (1)		$	61.1	$	36.8	$	24.3	66	%	Adjusted EBITDA (1)			$	327.5	$	61.1	$	266.4	436	%
Depreciation, depletion and amortization	Depreciation, depletion and amortization		(68.3)		(106.0)		37.7		36	%	Depreciation, depletion and amortization			(72.9)		(68.3)		(4.6)		(7)	%
Asset retirement obligation expenses	Asset retirement obligation expenses		(15.9)		(17.6)		1.7		10	%	Asset retirement obligation expenses			(15.0)		(15.9)		0.9		6	%
Restructuring charges	Restructuring charges		(2.1)		(6.5)		4.4		68	%	Restructuring charges			(1.6)		(2.1)		0.5		24	%
Transaction costs related to joint ventures			—		(4.2)		4.2		100	%

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		1.5		0.7		0.8		114	%	Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates			0.6		1.5		(0.9)		(60)	%
Interest expense	Interest expense		(52.4)		(33.1)		(19.3)		(58)	%	Interest expense			(39.4)		(52.4)		13.0		25	%
Gain on early debt extinguishment			3.5		—		3.5		n.m.
Net (loss) gain on early debt extinguishment											Net (loss) gain on early debt extinguishment			(23.5)		3.5		(27.0)		(771)	%
Interest income	Interest income		1.5		3.1		(1.6)		(52)	%	Interest income			0.5		1.5		(1.0)		(67)	%

Unrealized losses on economic hedges			(1.9)		(2.2)		0.3		14	%
Unrealized (losses) gains on non-coal trading derivative contracts			(7.6)		0.1		(7.7)		(7,700)	%
Unrealized losses on derivative contracts related to forecasted sales											Unrealized losses on derivative contracts related to forecasted sales			(301.0)		(1.9)		(299.1)		(15,742)	%
Unrealized gains (losses) on foreign currency option contracts											Unrealized gains (losses) on foreign currency option contracts			3.3		(7.6)		10.9		143	%
Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition		1.1		2.6		(1.5)		(58)	%	Take-or-pay contract-based intangible recognition			0.7		1.1		(0.4)		(36)	%
Income tax benefit (provision)			1.8		(3.0)		4.8		160	%
Income tax benefit											Income tax benefit			1.0		1.8		(0.8)		(44)	%
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		$	(77.7)	$	(129.3)	$	51.6	40	%	Loss from continuing operations, net of income taxes			$	(119.8)	$	(77.7)	$	(42.1)	(54)	%

Table of Contents

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


		Three Months Ended	Increase (Decrease)
		March 31,	to Income									Three Months Ended March 31,	(Decrease) Increase to Income
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Seaborne Thermal Mining	Seaborne Thermal Mining		$	(21.1)	$	(22.2)	$	1.1	5	%	Seaborne Thermal Mining			$	(24.0)	$	(21.1)	$	(2.9)	(14)	%
Seaborne Metallurgical Mining	Seaborne Metallurgical Mining		(16.5)		(24.8)		8.3		33	%	Seaborne Metallurgical Mining			(19.9)		(16.5)		(3.4)		(21)	%
Powder River Basin Mining	Powder River Basin Mining		(9.6)		(35.2)		25.6		73	%	Powder River Basin Mining			(10.5)		(9.6)		(0.9)		(9)	%
Other U.S. Thermal Mining	Other U.S. Thermal Mining		(17.2)		(21.4)		4.2		20	%	Other U.S. Thermal Mining			(15.7)		(17.2)		1.5		9	%
Corporate and Other	Corporate and Other		(3.9)		(2.4)		(1.5)		(63)	%	Corporate and Other			(2.8)		(3.9)		1.1		28	%
Total	Total		$	(68.3)	$	(106.0)	$	37.7	36	%	Total			$	(72.9)	$	(68.3)	$	(4.6)	(7)	%

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
March 31,
2021 2020
Seaborne Thermal Mining $ 1.87 $ 1.90
Seaborne Metallurgical Mining 1.00 2.68
Powder River Basin Mining 0.23 0.79
Other U.S. Thermal Mining 1.12 1.06

~~Table of Contents~~


	Three Months Ended March 31,
		2022		2021
Seaborne Thermal Mining		$	2.48	$	1.87
Seaborne Metallurgical Mining		2.12		1.00
Powder River Basin Mining		0.33		0.23
Other U.S. Thermal Mining		1.17		1.12

Depreciation, depletion and amortization expense ~~decreased~~increased during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year primarily due to increased depletion. The increase in the weighted-average depletion rate per ton for the Seaborne Thermal Mining segment during the three months ended March 31, 2022 compared to the same period in the prior year reflects the impact of the ~~asset impairment recorded at~~transition to the ~~North Antelope Rochelle Mine during the second quarter of 2020 ($25.2 million) and decreased depletion driven by lower sales volumes ($6.6 million).~~United Wambo Joint Venture. The ~~decrease~~increase in the weighted-average depletion rate per ton for the Seaborne Metallurgical Mining segment during the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year reflects the volume and mix variances which impacted the Company’s ~~revenues~~revenue as described above.

Interest Expense. The decrease in ~~the weighted-average depletion rate per ton for the Powder River Basin Mining segment~~interest expense during the three months ended March 31, ~~2021 compared to the same period in the~~2022 was primarily driven by prior year ~~reflects the asset impairment recorded during the second quarter of 2020.~~

~~Restructuring Charges.~~ Restructuring charges decreased during the three months ended March 31, 2021 compared to the same period in the prior year as the result of workforce reductions made across the organization during the prior year through the use of involuntary and voluntary reductions, as discussed in Note 14. “Other Events” to the accompanying unaudited condensed consolidated financial statements.

~~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 of 2020.~~

~~Interest Expense.~~ ~~Interest expense increased during the three months ended March 31, 2021 compared to the same period in the prior year as the result of~~ a series of refinancing transactions completed by the Company ~~during the first quarter of 2021, which included a senior notes exchange, a revolving credit facility exchange and various amendments to the Company’s existing debt agreements~~($10.6 million) as further ~~discussed~~described in Note 11. “Long-term Debt” to the ~~accompanying unaudited condensed consolidated financial statements.~~Annual Report on Form 10-K for the year ended December 31, 2021.

Net (Loss) Gain on Early Debt Extinguishment. The ~~gain~~loss recognized during the three months ended March 31, ~~2021~~2022 was primarily related to the ~~senior~~redemption of existing notes ~~exchange completed~~ during the ~~first quarter of 2021~~period as further discussed in Note 11. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements.

Unrealized ~~(Losses) Gains~~Losses on ~~Non-Coal Trading~~ Derivative ~~Contracts.~~Contracts Related to Forecasted Sales. Unrealized ~~(losses) gains~~losses primarily relate to mark-to-market activity ~~from economic hedge activities intended~~on derivatives related to ~~hedge~~forecasted sales. For additional information, refer to Note 7. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

Unrealized Gains (Losses) on Foreign Currency Option Contracts. Unrealized gains (losses) primarily relate to mark-to-market activity on foreign currency option contracts. For additional information, refer to Note 7. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements.

~~Income Tax Benefit (Provision)~~

. The decrease in the income tax provision for the three months ended March 31, 2021 compared to the same period in the prior year was primarily due to differences in forecasted taxable income, partially offset by an increase in the provision related to the remeasurement

Table of ~~foreign income tax accounts. Refer to Note 10. “Income Taxes” to the accompanying unaudited condensed consolidated financial statements for additional information.~~Contents

Net Loss Attributable to Common Stockholders

The following table presents net loss attributable to common stockholders:


		Three Months Ended	Increase
		March 31,	to Income									Three Months Ended March 31,	(Decrease) Increase to Income
			2021		2020		$		%					2022		2021		$		%
		(Dollars in millions)										(Dollars in millions)
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		$	(77.7)	$	(129.3)	$	51.6	40	%	Loss from continuing operations, net of income taxes			$	(119.8)	$	(77.7)	$	(42.1)	(54)	%
Loss from discontinued operations, net of income taxes	Loss from discontinued operations, net of income taxes		(2.0)		(2.2)		0.2		9	%	Loss from discontinued operations, net of income taxes			(0.8)		(2.0)		1.2		60	%
Net loss	Net loss		(79.7)		(131.5)		51.8		39	%	Net loss			(120.6)		(79.7)		(40.9)		(51)	%
Less: Net income (loss) attributable to noncontrolling interests			0.4		(1.8)		2.2		122	%
Less: Net (loss) income attributable to noncontrolling interests											Less: Net (loss) income attributable to noncontrolling interests			(1.1)		0.4		(1.5)		(375)	%
Net loss attributable to common stockholders	Net loss attributable to common stockholders		$	(80.1)	$	(129.7)	$	49.6	38	%	Net loss attributable to common stockholders			$	(119.5)	$	(80.1)	$	(39.4)	(49)	%

~~Table of Contents~~

Diluted Earnings per Share (EPS)

The following table presents diluted EPS:


		Three Months Ended	Increase
		March 31,	to EPS									Three Months Ended March 31,	(Decrease) Increase to EPS
			2021		2020		$		%					2022		2021		$		%
Diluted EPS attributable to common stockholders:	Diluted EPS attributable to common stockholders:										Diluted EPS attributable to common stockholders:
Loss from continuing operations	Loss from continuing operations		$	(0.79)	$	(1.31)	$	0.52	40	%	Loss from continuing operations			$	(0.87)	$	(0.79)	$	(0.08)	(10)	%
Loss from discontinued operations	Loss from discontinued operations		(0.02)		(0.02)		—		—	%	Loss from discontinued operations			(0.01)		(0.02)		0.01		50	%
Net loss attributable to common stockholders	Net loss attributable to common stockholders		$	(0.81)	$	(1.33)	$	0.52	39	%	Net loss attributable to common stockholders			$	(0.88)	$	(0.81)	$	(0.07)	(9)	%

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 ~~98.4~~136.2 million and ~~97.2~~98.4 million for the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, respectively.

Reconciliation of Non-GAAP Financial Measures

Adjusted EBITDA is defined as 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
		March 31,						Three Months Ended March 31,
			2021		2020				2022		2021
			(Dollars in millions)						(Dollars in millions)
Loss from continuing operations, net of income taxes	Loss from continuing operations, net of income taxes		$	(77.7)	$	(129.3)	Loss from continuing operations, net of income taxes		$	(119.8)	$	(77.7)
Depreciation, depletion and amortization	Depreciation, depletion and amortization		68.3		106.0		Depreciation, depletion and amortization		72.9		68.3
Asset retirement obligation expenses	Asset retirement obligation expenses		15.9		17.6		Asset retirement obligation expenses		15.0		15.9
Restructuring charges	Restructuring charges		2.1		6.5		Restructuring charges		1.6		2.1
Transaction costs related to joint ventures			—		4.2

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		(1.5)		(0.7)		Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates		(0.6)		(1.5)
Interest expense	Interest expense		52.4		33.1		Interest expense		39.4		52.4
Gain on early debt extinguishment			(3.5)		—
Net loss (gain) on early debt extinguishment							Net loss (gain) on early debt extinguishment		23.5		(3.5)
Interest income	Interest income		(1.5)		(3.1)		Interest income		(0.5)		(1.5)

Unrealized losses on economic hedges			1.9		2.2
Unrealized losses (gains) on non-coal trading derivative contracts			7.6		(0.1)
Unrealized losses on derivative contracts related to forecasted sales							Unrealized losses on derivative contracts related to forecasted sales		301.0		1.9
Unrealized (gains) losses on foreign currency option contracts							Unrealized (gains) losses on foreign currency option contracts		(3.3)		7.6
Take-or-pay contract-based intangible recognition	Take-or-pay contract-based intangible recognition		(1.1)		(2.6)		Take-or-pay contract-based intangible recognition		(0.7)		(1.1)
Income tax (benefit) provision			(1.8)		3.0
Income tax benefit							Income tax benefit		(1.0)		(1.8)
Total Adjusted EBITDA	Total Adjusted EBITDA		$	61.1	$	36.8	Total Adjusted EBITDA		$	327.5	$	61.1

Table of Contents

Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenue by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton, and are reconciled to operating costs and expenses as follows:


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Operating costs and expenses		$	699.0	$	582.6
Unrealized gains (losses) on foreign currency option contracts		3.3		(7.6)
Take-or-pay contract-based intangible recognition		0.7		1.1

Net periodic benefit credit, excluding service cost		(12.2)		(8.7)
Total Reporting Segment Costs		$	690.8	$	567.4

The following table presents Reporting Segment Costs by reporting segment:


	Three Months Ended March 31,
		2022		2021
		(Dollars in millions)
Seaborne Thermal Mining		$	160.7	$	147.9
Seaborne Metallurgical Mining		140.3		109.9
Powder River Basin Mining		243.6		198.3
Other U.S. Thermal Mining		153.1		113.1
Corporate and Other		(6.9)		(1.8)
Total Reporting Segment Costs		$	690.8	$	567.4

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


	Three Months Ended March 31, 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	3.8		1.2		20.6		4.2

Revenue	$	251.2	$	321.3	$	251.2	$	203.1
Reporting Segment Costs	160.7		140.3		243.6		153.1
Adjusted EBITDA	$	90.5	$	181.0	$	7.6	$	50.0

Revenue per Ton	$	66.86	$	258.43	$	12.18	$	48.46
Costs per Ton	42.77		112.87		11.81		36.54
Adjusted EBITDA Margin per Ton	$	24.09	$	145.56	$	0.37	$	11.92

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Revenues per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenues per Ton less Adjusted EBITDA Margin per Ton, and are reconciled to operating costs and expenses as follows:

Three Months Ended
March 31,
2021 2020
(Dollars in millions)
Operating costs and expenses $ 582.6 $ 779.5
Unrealized (losses) gains on non-coal trading derivative contracts (7.6) 0.1
Take-or-pay contract-based intangible recognition 1.1 2.6
Net periodic benefit (credit) costs, excluding service cost (8.7) 2.8
Total Reporting Segment Costs $ 567.4 $ 785.0

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

Three Months Ended
March 31,
2021 2020
(Dollars in millions)
Seaborne Thermal Mining $ 147.9 $ 146.0
Seaborne Metallurgical Mining 109.9 225.9
Powder River Basin Mining 198.3 241.2
Other U.S. Thermal Mining 113.1 153.8
Corporate and Other (1.8) 18.1
Total Reporting Segment Costs $ 567.4 $ 785.0

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

Three Months Ended March 31, 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 4.1 1.0 20.7 3.9
Revenues $ 176.4 $ 87.5 $ 228.4 $ 149.3
Reporting Segment Costs 147.9 109.9 198.3 113.1
Adjusted EBITDA $ 28.5 $ (22.4) $ 30.1 $ 36.2
Revenues per Ton $ 43.36 $ 87.47 $ 11.01 $ 38.76
Costs per Ton 36.36 109.89 9.56 29.37
Adjusted EBITDA Margin per Ton $ 7.00 $ (22.42) $ 1.45 $ 9.39

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		Three Months Ended March 31, 2020									Three Months Ended March 31, 2021
		Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining			Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
		(Amounts in millions, except per ton data)									(Amounts in millions, except per ton data)
Tons sold	Tons sold	4.6		2.0		23.5		4.9		Tons sold	4.1		1.0		20.7		3.9

Revenues		$	201.1	$	193.2	$	266.6	$	192.3
Revenue										Revenue	$	176.4	$	87.5	$	228.4	$	149.3
Reporting Segment Costs	Reporting Segment Costs	146.0		225.9		241.2		153.8		Reporting Segment Costs	147.9		109.9		198.3		113.1
Adjusted EBITDA	Adjusted EBITDA	$	55.1	$	(32.7)	$	25.4	$	38.5	Adjusted EBITDA	$	28.5	$	(22.4)	$	30.1	$	36.2

Revenues per Ton		$	44.10	$	95.65	$	11.36	$	39.25
Revenue per Ton										Revenue per Ton	$	43.36	$	87.47	$	11.01	$	38.76
Costs per Ton	Costs per Ton	32.03		111.82		10.28		31.39		Costs per Ton	36.36		109.89		9.56		29.37
Adjusted EBITDA Margin per Ton	Adjusted EBITDA Margin per Ton	$	12.07	$	(16.17)	$	1.08	$	7.86	Adjusted EBITDA Margin per Ton	$	7.00	$	(22.42)	$	1.45	$	9.39

Free Cash Flow is defined as net cash (used in) provided by ~~(used in)~~ operating activities less 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.

~~Outlook~~

As part of its normal planning and forecasting process, Peabody utilizes a broad approach to develop macroeconomic assumptions for key variables, including country-level gross domestic product, industrial production, fixed asset investment and third-party inputs, driving detailed supply and demand projections for key demand centers for coal, electricity generation and steel. Specific to the U.S., the Company evaluates individual plant needs, including expected retirements, on a plant by plant basis in developing its demand models. Supply models and cost curves concentrate on major supply regions/countries that impact the regions in which the Company operates.

The Company’s estimates involve risks and uncertainties and are subject to change based on various factors as summarized in the “Cautionary Notice Regarding Forward-Looking Statements” section contained within this Item 2.

The Company’s near-term outlook is intended to coincide with the next 12 to 24 months, with subsequent periods addressed in its long-term outlook. Peabody is continuing to monitor the rapidly evolving COVID-19 pandemic and any impacts related to both its near-term and long-term outlook.

~~Near-Term Outlook~~

Within the global coal industry, supply and demand disruptions have been widespread as the COVID-19 pandemic has forced country-wide lockdowns and regional restrictions. Future COVID-19-related developments are unknown, including the duration, severity, scope and the necessary government actions to limit the spread of COVID-19.

Within the seaborne metallurgical coal market, the imbalance between Australian export and Chinese delivered prices remains wide, with the delivered price into China trading at roughly double those seen free on board Australia as the unofficial ban on Australian coals remains in place. In addition, increased COVID-19 concerns in India are further weighing on Australian hard coking coal pricing. These factors continue to pressure the seaborne metallurgical coal market despite global steel production increasing 5% year-over-year.

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Within the seaborne thermal coal market, tight supplies and low inventory levels have kept Newcastle thermal coal pricing at improved levels year-to-date. China’s domestic thermal coal supply remains hampered by heightened safety inspections. In addition, India’s thermal coal stockpiles have been falling gradually since mid-December as government-owned plants have reduced intake and there has been a delay in typical restocking ahead of the monsoon season in June. As of the end of March 2021, India’s plant inventory levels were estimated at approximately 15 days burn versus 28 days a year ago.

In the United States, overall electricity demand increased 2% year-over-year, positively impacted by cold weather during the three months ended March 31, 2021. Electricity generation from thermal coal has increased by 37% year-over-year as a result of higher natural gas prices. This has positively impacted coal’s share of electricity generation, with a rise to approximately 24% for the three months ended March 31, 2021, while causing natural gas’s share to decline to approximately 34%. Stronger coal use has contributed to decreasing coal stockpile levels. Since December 2020, coal inventories have fallen by approximately 20 million tons. Through the three months ended March 31, 2021, utility consumption of PRB coal rose approximately 35% compared to the prior year period. Ultimately, U.S. thermal coal demand will be dependent on general economic conditions, weather, natural gas prices, utility inventory levels and other factors.

~~Long-Term Outlook~~

There were no significant changes to the Company’s Long-Term Outlook subsequent to December 31, 2020. Information regarding the Company’s Long-Term Outlook is outlined in Part II. Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in its Annual Report on Form 10-K for the year ended December 31, 2020.


	Three Months Ended March 31,
	2022		2021
	(Dollars in millions)
Net cash (used in) provided by operating activities	$	(273.7)	$	71.0
Net cash provided by (used in) investing activities	35.2		(93.2)

Free Cash Flow	$	(238.5)	$	(22.2)

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.~~2021.

Regulatory Matters - U.S.

~~Clean~~National Ambient Air ~~Act (CAA).~~Quality Standards (NAAQS) ~~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.~~

. The Clean Air Act (CAA) requires the ~~EPA~~United States Environmental Protection Agency (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 promulgated in 2015, including current secondary standards, and subsequently promulgated final standards to this effect. 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 ~~State~~(D.C. Circuit). The litigation is currently in abeyance following a motion filed by the EPA to allow for review of ~~New York v. EPA, No. 21-1028.~~the standards.

The EPA also proposed in 2020 to retain the particulate matter (PM) standards ~~promulgated~~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, State~~organizations. The case is currently in abeyance following a motion filed by the EPA to allow for review of ~~California v.~~the standards.

On March 11, 2022, the EPA ~~No. 21-2014.~~announced their Clean Air Act ‘good neighbor’ proposed rule. The rule would double the number of covered states, set first-time limits on certain industrial source plant boilers and require daily limits on emissions from large coal-fired power plants. The EPA estimates that by 2026 the compliance cost will be $1.1 billion.

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 ~~the implementation for~~ other NAAQS for nitrogen ~~oxide~~dioxide (NO2) and SOsulfur dioxide (SO2), although these standards are not subject to a statutorily-required review until 2023 for NO2 ~~although the EPA promulgated a final rule on March 18, 2019 that retains, without revision, the existing NAAQS~~and 2024 for SO2 ~~of 75 ppb averaged over an hour.~~

~~EPA Regulation of Greenhouse Gas Emissions from Existing Fossil Fuel-Fired EGUs.~~ On October 23, 2015, the EPA published a final rule in the Federal Register regulating greenhouse gas emissions from existing fossil fuel-fired 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).

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The EPA has since 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.

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 ~~emissions~~(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 as well as NOx emissions in 21 states targeted by the CSAPR Update Rule. On March 15,~~April 2021, the EPA ~~signed~~published a final rule in the Federal Register 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, which was based on the 2008 ozone standard.

In the same rule, the EPA determined that 9 states dodid not significantly contribute to downwind nonattainment and/or maintenance issues and therefore dodid not ~~need~~require additional emission reductions. ~~For 12 other states, however,~~The EPA subsequently issued Federal Implementation Plans (FIPs) to lower state ozone season ~~NOx~~NOx budgets in 2021 to 2024 ~~although limited emission trading can be used~~in the affected states. A petition for ~~compliance.~~review challenging the 2021 rule has been filed in the D.C. Circuit and briefing in this litigation has been completed, but this does not stay the effectiveness of the rule.

In addition, on February 28, 2022, the EPA released a proposed rule for additional FIPs to address interstate air pollution from fossil-fuel power plants in 25 states and certain industrial sources in 23 states. This rule is based on the more stringent 2015 ozone NAAQS and would, if finalized, affect some of the states covered by previous rules, but also include several new states, including states in the western United States.

Mercury and Air Toxic Standards (MATS). The EPA published the final MATS rule in the Federal Register in 2012. The MATS rule revised the ~~NSPS~~new source performance standards (NSPS) for ~~nitrogen oxides,~~NOx, SO2 and PM for new and modified coal-fueled electricity generating plants, and imposed ~~MACT~~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 ~~have been~~were challenged in the D.C. Circuit ~~and~~but this litigation was placed in abeyance.

~~CWA Definition~~ On February 9, 2022 the EPA 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 powerplants under Clean Air Act section 112. In the same proposal, the EPA is also soliciting comments on the performance and cost of ~~“Waters~~new or improved technologies to control HAPs from these powerplants as part of the ~~United States”~~agency’s review of related residual risk and technology review standards.

Clean Water Act (CWA). ~~In January~~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 ~~and~~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 ~~Corps finalized the Navigable Waters Protection Rule~~rule. The EPA, however, plans to ~~revise the definition of “Waters of the United States” and thereby establish the scope of federal regulatory authority under the CWA. A federal district judge~~issue another proposal in Colorado preliminarily enjoined the Navigable Waters Protection Rule in the State of Colorado on June 19, 2020, but the new rule took effect in all other states on June 22, 2020. The U.S. Court of Appeals for the Tenth Circuit reversed the preliminary injunction in Colorado on March 2, 2021, so the Navigable Waters Protection Rule is in effect nationwide. Litigation over2022 that would supersede the 2020 ~~Navigable Waters Protection Rule remains pending in several federal district courts.~~rule.

Regulatory Matters - Australia

The ~~Australian mining industry is regulated by Australian~~outcome of Australia’s federal state and local governments with respect to environmental issues such as land reclamation, water quality, air quality, dust control, noise, planning issues (such as approvals to expand existing mines or to develop new mines) and health and safety issues. The Australian federal government retains control over the level of foreign investment and export approvals. Industrial relations are regulated under both 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 returned or security released after satisfactory reclamation is 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~~) in Australian coal mines from 12,500ppm to 5,000ppm. 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~~election on May 21, 2022 has the potential to ~~affect underground mines operating~~impact federal environmental, taxation, labor market and other legislation governing Australian mining operations.

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On March 15, 2022, the Full Court of the Federal Court of Australia overturned the decision in CO2 ~~rich~~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 ~~seams,~~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 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.

As part of the Queensland Government’s 2019-20 Budget, it committed to freeze royalty rates on coal and minerals for three years provided companies voluntarily contribute to the Resources Community Infrastructure Fund. The royalty freeze is due to end in June 2022 and the Queensland Government has not established a replacement rate.

The New South Wales Mining and Geoscience Department will be undertaking consultation with respect to the manner for calculating mining royalties in New South Wales between April and June 2022 as part of a proposed redraft of the Mining Royalties (COAL) – Ministerial Determination under Section 283(5) of the Mining Act 1992.

Risks Related to Global Climate Change

Peabody recognizes that climate change is occurring and that human activity, including the ~~primary~~use of fossil fuels, contributes to greenhouse gas (GHG) emissions. The Company’s largest contribution to GHG emissions occurs indirectly, through the coal ~~seam~~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 ~~Metropolitan Mine. Importantly,~~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 ~~minimum three-year~~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 ~~period applies~~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 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 ~~any change~~balanced-source energy policies and regulations.

Global climate issues continue to ~~standards.~~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 legislation and regulation and international accords regarding climate change. Such developments are described within Part I, Item 1. “Business” in the Company’s Annual Report on Form 10-K for 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.

~~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 such legislation has been signed into law. While it is possible that the U.S. will adopt legislation in the future, the timing and specific requirements of any such legislation are uncertain. 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.” In particular, in 2015, the EPA announced final rules (known as the CPP) for regulating carbon dioxide emissions from existing and new fossil fuel-fired EGUs. Twenty-seven states and governmental entities, as well as utilities, industry groups, trade associations, coal companies (including Peabody), and other entities, challenged the CPP in federal court. Implementation of the CPP was stayed by the U.S. Supreme Court pending resolution of its legal challenges. In October 2017, the EPA proposed to change its legal interpretation of section 111(d) of the CAA, the authority that the agency relied on for the original CPP. The EPA relied on the proposed reinterpretation until August 2018, when it proposed the Affordable Clean Energy Rule (the ACE Rule) to replace the CPP with a system where states would develop emissions reduction plans using BSER measures (essentially efficiency heat rate improvements), and the EPA would approve the state plans if they use EPA-approved candidate technologies. The EPA thereafter repealed the CPP and promulgated the final ACE Rule on July 8, 2019. On January 19, 2021, the D.C. Circuit Court of Appeals vacated and remanded the ACE Rule, including the repeal of the CPP and amendments to implementing regulations that extended compliance timelines.

Several changes in the NSR program 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 and herein. 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. Clean Air Act standards, known as new source performance standards, 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.

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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.

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 specificity for a regulatory framework to achieve that goal. The Company anticipates a series of executive actions and/or orders from the current presidential administration aimed at curbing emission levels.

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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 that the focus of energy policy will be on 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 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.

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 proposed rules. The proposal is open for public comment through at least May 21, 2022.

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 ~~from time to time,~~ 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.

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.”

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Liquidity

As of March 31, ~~2021,~~2022, the Company’s cash balances totaled ~~$580.2~~$823.3 million, including approximately ~~$396~~$331 million held by U.S. subsidiaries, ~~and $157~~$473 million held by Australian subsidiaries, ~~approximately $104 million of which was held by~~and the ~~subsidiaries that conduct the operations of its Wilpinjong Mine. The Company’s remaining balance was~~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 $213 million at March 31, 2022. A significant majority of the cash held by ~~its~~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 first quarter of 2022, the Company repatriated approximately $200 million. If additional foreign-held cash is repatriated in the future, the Company does not expect restrictions or potential taxes will have a material effect to its near-term liquidity.

The Company’s available liquidity declined from $995.9 million as of December 31, 2021 to $841.5 million as of March 31, 2022. Available liquidity was comprised of the following:


	March 31, 2022		December 31, 2021
	(Dollars in millions)
Cash and cash equivalents	$	823.3	$	954.3
Credit facility availability	16.6		15.3
Accounts receivable securitization program availability	1.6		26.3
Total liquidity	$	841.5	$	995.9

Subsequent to March 31, 2022, the Company executed an amendment to its credit facility to reduce its capacity by approximately $17 million and to make allowable certain previously restricted payments for joint venture investments. The amendment creates an investment basket which allows payments of $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 has no contractual commitment for such joint venture 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.

At March 4, 2022, the Company held coal derivative contracts in aggregate of 2.3 million metric tons. The majority of these contracts were entered into in the first half of 2021 and related to 1.9 million metric tons of production at the Wambo Underground Mine in the Company’s Seaborne Thermal Mining segment, which were expected to be mined and settled at a rate of 1.2 million metric tons in 2022 and 0.7 million metric tons in 2023. These hedge contracts were put in place to support the profitability of the mine, securing anticipated average prices of $84 per metric ton through mid-2023. The remaining hedges relate to brokered coal transactions and other blending and optimization activities, which will settle throughout 2022.

High demand and tight supply for coal globally 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 for March closed at $419.50 per metric ton on March 4, 2022, which was 148% above the closing index price of $169.17 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, and were $481.7 million at March 31, 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.

Of the Company's total expected 2022 export sales from its Seaborne Thermal Mining segment, approximately 6% is hedged and approximately 53% is unpriced. The unpriced volume will benefit if the current pricing environment persists.

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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 Credit Agreement provides for a $150 million unsecured revolving credit facility (the Revolving Facility), which will mature on April 1, 2025 and bears interest at a rate of 10.0% per annum on drawn amounts. The Revolving Facility is intended to support the Company’s near-term liquidity requirements, particularly with respect to the cash margin requirements associated with the Company’s coal derivative contracts.

To reduce exposure to additional margin requirements, subsequent to March 31, 2022, the Company converted 0.8 million metric tons of financial hedges into fixed price physical sales over the next 12 months. With these transactions, 1.4 million metric tons remain outstanding with 0.9 million metric tons projected to settle over the remainder of 2022. On April 29, 2022, the Company had $535.9 million of margin posted. For additional information regarding the Company’s coal derivative contracts and related margin requirements, refer to Part I, Item 3. “Quantitative and Qualitative Disclosures About Market Risk” of this Quarterly Report.

Indebtedness

The Company’s total funded indebtedness (Indebtedness) as of March 31, 2022 and December 31, 2021 is presented in the table below.


Debt Instrument (defined below, as applicable)	March 31, 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)	193.6		193.9
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	188.8		206.0
6.375% Senior Secured Notes due March 2025 (2025 Notes)	77.5		334.9
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	321.8		322.8
3.250% Convertible Senior Notes due March 2028 (2028 Convertible Notes)	320.0		—


Finance lease obligations	27.6		29.3
Less: Debt issuance costs	(31.2)		(34.8)
	1,098.1		1,137.8
Less: Current portion of long-term debt	19.1		59.6
Long-term debt	$	1,079.0	$	1,078.2

The Company’s Indebtedness will require estimated principal and interest payments, assuming interest rates in effect at March 31, 2022, of approximately $60 million during the nine months ending December 31, 2022, and approximately $70 million in 2023, $455 million in 2024, $405 million in 2025, and $355 million thereafter.

Cash payments for interest related to the Company’s Indebtedness and financial assurance instruments amounted to $37.2 million and $56.3 million during the three months ended March 31, 2022 and 2021, respectively.

2021 Financing Activity

During the first quarter of 2021, the Company completed a series of 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. These transactions included a senior notes exchange and related consent solicitation, a revolving credit facility exchange, various amendments to the Company’s existing debt agreements, and completion of a related surety transaction support agreement with the Company’s surety bond providers.

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~~The Company’s available liquidity declined from $728.7 million as of December 31, 2020~~Subsequent to ~~$603.8 million as of March 31, 2021. Available liquidity, which excluded $43.5 million of restricted cash as of March 31, 2021, was comprised of the following:~~

March 31, 2021 December 31, 2020
(Dollars in millions)
Cash and cash equivalents $ 580.2 $ 709.2
Revolving credit facility availability 22.8 0.2
Accounts receivable securitization program availability 0.8 19.3
Total liquidity $ 603.8 $ 728.7

~~Refinancing and Related Transactions~~

~~During the fourth quarter of 2020 and~~these transactions in the first quarter of 2021, the Company completed additional financing transactions during 2021 intended to improve its capital structure. Such transactions 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.

In the event of allowable open market purchases of its debt, the terms of the 2024 Peabody Notes and the letter of credit facility entered into a series of interrelated agreements with its surety bond providers, the revolving lenders under its credit agreement and certain holders of its senior secured notes to extend a significant portion of its near-term debt maturities to December 2024 and to stabilize collateral requirements for its existing surety bond portfolio. Such agreements and related activities are described below.

~~Organizational Realignment~~

~~In July and August 2020,~~by the Company ~~effected certain changes to its corporate structure~~ in ~~contemplation of a debt-for-debt exchange, which included, among other steps, the formation of certain wholly-owned subsidiaries (the Co-Issuers). In~~ connection with the ~~change in structure,~~2021 financing activity (Company LC Agreement) require the ~~Company’s subsidiary which owns~~Company to make a mandatory repurchase offer to those debt and ~~operates its Wilpinjong Mine in Australia became a subsidiary~~lien holders. In general, the repurchase offers equate to 25% of the ~~Co-Issuers.~~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 ~~Co-Issuers~~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 94.940% of their aggregate accreted value, plus accrued and ~~the Wilpinjong subsidiary were designated as unrestricted subsidiaries~~unpaid interest, and a concurrent repurchase offer of priority lien obligations under the ~~Company’s Credit Agreement~~Company LC Agreement. The offer resulted in the valid tender and ~~its senior notes’ indenture (the Existing Indenture). In connection with these actions,~~purchase of $0.1 million aggregate accreted value of 2024 Peabody Notes and $30.0 million aggregate principal and commitment amounts under the Company ~~contributed $100.0 million to~~LC Agreement during the ~~Co-Issuers to provide~~three months ended March 31, 2022. The Company’s purchase of the ~~Wilpinjong Mine with operating liquidity~~principal and ~~address its capital needs over the next twelve months.~~

~~Surety Agreement~~

~~In November 2020,~~commitment amounts under the Company ~~entered into a surety transaction support agreement (Surety Agreement) with the providers of 99% of its surety bond portfolio (Participating Sureties) to resolve previous collateral demands made~~LC Agreement was effected by the ~~Participating Sureties. In accordance with the Surety Agreement, the Company initially provided $75.0~~posting of $28.5 million of collateral inwith the ~~form of letters of credit.~~

~~Upon completion of~~administrative agent and did not reduce the ~~Refinancing Transactions, as defined below, other provisions of~~availability under the ~~Surety Agreement became effective. In particular,~~facility. During the three months ended March 31, 2022, the Company ~~granted second liens on $200.0 million~~made no other open market purchases of ~~certain mining equipment~~its debt.

The 2024 Co-Issuer Notes and ~~will post an additional $25.0 million~~the Co-Issuer Term Loans are also subject to mandatory prepayment offers at the end of ~~collateral per year from~~each six-month period, beginning with June 30, 2021, ~~through 2024 for~~whereby 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~~Excess Cash Flow (as defined in the ~~Surety Agreement) in any twelve-month~~2024 Co-Issuer Notes indenture) generated by the Wilpinjong Mine during each such period will 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 ~~have asset sales in excess~~declined at the option of ~~$10.0 million. Further,~~ the ~~Participating Sureties have agreed to a standstill through~~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 ~~which time,~~ the ~~Participating Sureties will not demand any additional collateral, draw~~three months ended March 31, 2022.

The 2021 financing activity and related agreements are more fully described in the Company’s Annual Report on ~~letters of credit posted~~Form 10-K for the ~~benefit~~year ended December 31, 2021, as filed with the U.S. Securities and Exchange Commission on February 18, 2022.

Retirement of ~~themselves, or cancel any existing surety bond.~~ 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 ~~will not~~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 ~~dividends or make share repurchases~~related premiums, fees and expenses relating to the offering of the 2028 Convertible Notes and the redemptions. The redemption of existing notes was deemed a debt extinguishment for accounting purposes. 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 ~~standstill period,~~three months ended March 31, 2022.

The 2028 Convertible Notes will mature on March 1, 2028, unless ~~otherwise agreed between parties.~~

~~Refinancing Transactions~~

~~On January 29, 2021 (the Settlement Date),~~earlier converted, redeemed or repurchased in accordance with their terms. The 2028 Convertible Notes will bear interest from March 1, 2022 at a rate of 3.250% per year payable semi-annually in arrears on March 1 and September 1 of each year, beginning on September 1, 2022. During the three months ended March 31, 2022, the Company ~~completed a series~~incurred interest expense of ~~transactions (collectively,~~$1.0 million related to 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.2028 Convertible Notes.

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~~Exchange Offer~~

~~On January 29, 2021,~~The 2028 Convertible Notes will be convertible at the option of the holders only in the following circumstances: (1) during any calendar quarter commencing after the calendar quarter ending on 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 ~~settled~~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 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 ~~exchange offer (Exchange Offer) pursuant~~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 ~~which $398.7~~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.

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 ~~its 6.000% Senior Secured~~2028 Convertible Notes ~~due March 2022 (2022 Notes) were validly tendered, accepted by~~are outstanding and not called for redemption as of the time the Company ~~and exchanged~~sends the related redemption notice. No sinking fund is provided for ~~aggregate consideration consisting of (a) $193.9 million aggregate principal amount of new 10.000% Senior Secured~~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 ~~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)~~at a cash ~~payment~~repurchase price equal to 100% 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.

~~Following the settlement of the Exchange Offer, approximately $60.3 million aggregate~~ principal amount of the ~~2022~~2028 Convertible Notes ~~remain outstanding and are governed by the Existing Indenture, as amended by the supplemental indenture described below.~~

~~As required under the Exchange Offer, the Company purchased $22.4 million Peabody Notes at 80% of their accreted value,~~to be repurchased, plus accrued and unpaid interest, ~~during~~if any, to, but excluding, the ~~first quarter of 2021 and recognized a related net gain of $3.5 million.~~fundamental change repurchase date.

~~Consent Solicitation~~Covenant Compliance

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~~was compliant with all relevant covenants under its debt agreements at March 31, 2022, including 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~~minimum 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) Peabody entering into a letter of credit facility (the Company LC Agreement), 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.~~

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 no revolving commitments or revolving loans under the Credit Agreement and the first lien net leverage ratio covenant was eliminated, effectively negating the compliance requirement at December 31, 2020 and prospectively. The Company LC Agreementwhich requires ~~that~~ the Company’s restricted subsidiaries to maintain minimum aggregate liquidity of $125.0 million at the end of each quarter through December 31, 2024. ~~As such,~~The Company’s restricted subsidiaries’ relevant liquidity ~~attributable to the Co-Issuers, its subsidiaries, and other unrestricted subsidiaries is excluded from the calculation. Liquidity calculated in this manner~~ amounted to ~~$475.3~~$610.0 million at March 31, ~~2021.~~

~~Other Debt Financing~~

The Refinancing Transactions did not significantly impact the Company’s existing senior secured term loan under the Credit Facility, or its $500.0 million of 6.375% senior secured notes due March 2025. The senior secured term loan had a balance of $387.3 million at March 31, 2021. 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.

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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 at March 31, 2021.

Considering the Refinancing Transactions, the Company expects to incur approximately $200 million of interest expense, including approximately $50 million of non-cash interest expense, during the year ended December 31, 2021.2022.

Accounts Receivable Securitization Program

As described in Note ~~16.~~15. “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 expires~~2017. The securitization program was amended in ~~2022. The program provides for up~~January 2022 to extend its maturity to January 2025 and reduce the 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 March 31, ~~2021,~~2022, the Company hadhad no outstanding borrowings and ~~$120.8~~$161.8 million of letters of credit issued under the program, which were primarily in support of portions of the Company’s ~~obligations for property and casualty insurance.~~reclamation obligations. The Company ~~had $43.5~~was required to post $24.7 million of cash collateral ~~posted~~ under the Securitization Program at March 31, ~~2021 due to outstanding letters~~2022.

Table of ~~credit temporarily exceeding the balance of eligible receivables at quarter-end.~~Contents

~~Capital Requirements~~

For 2021, the Company is targeting capital expenditures of approximately $225 million, which includes approximately $135 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.

Cash Flows and Free Cash Flow

The following table summarizes the Company’s cash flows for the three months ended March 31, ~~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.

Three Months Ended March 31,
2021 2020
(Dollars in millions)
Net cash provided by (used in) operating activities $ 71.0 $ (4.7)
Net cash used in investing activities (93.2) (37.1)
Net cash used in financing activities (63.3) (7.9)
Net change in cash, cash equivalents and restricted cash (85.5) (49.7)
Cash, cash equivalents and restricted cash at beginning of period 709.2 732.2
Cash, cash equivalents and restricted cash at end of period $ 623.7 $ 682.5
Net cash provided by (used in) operating activities $ 71.0 $ (4.7)
Net cash used in investing activities (93.2) (37.1)
Free Cash Flow $ (22.2) $ (41.8)

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	Three Months Ended March 31,
	2022		2021
	(Dollars in millions)
Net cash (used in) provided by operating activities	$	(273.7)	$	71.0
Net cash provided by (used in) investing activities	35.2		(93.2)
Net cash provided by (used in) financing activities	132.2		(63.3)
Net change in cash, cash equivalents and restricted cash	(106.3)		(85.5)
Cash, cash equivalents and restricted cash at beginning of period	954.3		709.2
Cash, cash equivalents and restricted cash at end of period	$	848.0	$	623.7

Net cash (used in) provided by operating activities	$	(273.7)	$	71.0
Net cash provided by (used in) investing activities	35.2		(93.2)

Free Cash Flow	$	(238.5)	$	(22.2)

Operating Activities. The ~~net~~ increase in net cash ~~(used in) provided by~~used in operating activities for the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year was driven by a year-over-year increase in cash ~~generated by Company’s mining operations and a favorable change in net cash flows~~utilized to satisfy the margin requirements associated with ~~its working capital~~derivative financial instruments ($~~59.0~~351.6 million).

Investing Activities. The increase in net cash ~~used in~~provided by investing activities for the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year was driven by higher distributions from related parties and joint ventures, on a net basis ($55.2 million), higher cash receipts from the Company’s equity method investments ($44.9 million), and lower capital expenditures ~~($19.0 million)~~ and ~~higher net contributions to joint ventures~~payments of capital accruals ($~~35.8~~25.0 million).

Financing Activities. The increase in net cash ~~used in~~provided by financing activities for the three months ended March 31, ~~2021~~2022 compared to the same period in the prior year was driven by ~~comparatively higher~~cash proceeds from long-term debt and common stock issuances ($545.0 million and $222.0 million, respectively), partially offset by higher repayments of debt principal ($~~33.0~~559.7 million)~~, including $37.3 million associated with the Refinancing Transactions,~~ and ~~the payment of deferred financing costs associated with the Refinancing Transactions~~higher distributions to non-controlling interests ($~~22.5~~13.7 million).

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 March 31, ~~2021,~~2022, such instruments included ~~$1,570.8~~$1,484.9 million of surety bonds and ~~$423.4~~$469.1 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.

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As of March 31, ~~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	$	1,394.5	$	42.1	$	87.6	$	30.9	$	15.7	$	1,570.8	Surety bonds and bank guarantees	$	1,312.1	$	42.1	$	81.6	$	30.9	$	18.2	$	1,484.9
Letters of credit outstanding under letter of credit facility	Letters of credit outstanding under letter of credit facility	198.3		90.4		7.5		5.0		—		301.2		Letters of credit outstanding under letter of credit facility	206.0		89.2		7.1		5.0		—		307.3
Letters of credit outstanding under accounts receivable securitization program	Letters of credit outstanding under accounts receivable securitization program	99.4		17.0		4.4		—		—		120.8		Letters of credit outstanding under accounts receivable securitization program	134.0		17.7		10.1		—		—		161.8
Other letters of credit		—		1.4		—		—		—		1.4

		1,692.2		150.9		99.5		35.9		15.7		1,994.2			1,652.1		149.0		98.8		35.9		18.2		1,954.0
Less: Letters of credit in support of surety bonds (4)	Less: Letters of credit in support of surety bonds (4)	(297.7)		(29.5)		—		(1.2)		—		(328.4)		Less: Letters of credit in support of surety bonds (4)	(332.6)		(30.2)		(2.4)		(1.2)		—		(366.4)
Less: Cash collateral in support of surety bonds (4)	Less: Cash collateral in support of surety bonds (4)	(15.0)		—		—		—		—		(15.0)		Less: Cash collateral in support of surety bonds (4)	(15.0)		—		—		—		—		(15.0)

Obligations supported, net	Obligations supported, net	$	1,379.5	$	121.4	$	99.5	$	34.7	$	15.7	$	1,650.8	Obligations supported, net	$	1,304.5	$	118.8	$	96.4	$	34.7	$	18.2	$	1,572.6

(1) Obligations include pension and ~~healthcare~~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 Company has also posted ~~$5.3~~$9.1 million in incremental collateral directly with the beneficiary that is not supported by a surety bond.

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.~~15. “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 March 31, ~~2021,~~2022, the Company had total asset retirement obligations of ~~$735.9~~$724.5 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.~~15. “Financial Instruments and Other Guarantees” in the Company’s unaudited condensed consolidated financial statements for a discussion of its accounts receivable securitization program and guarantees and other financial instruments with off-balance-sheet risk.

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.

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At March 31, ~~2021,~~2022, the Company identified certain assets with an aggregate carrying value of approximately ~~$1.2~~$0.5 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 ~~for recoverability~~ as of March 31, ~~2021~~2022 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 March 31, ~~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 March 31, 2022, the Company held coal derivative contracts related to a portion of its forecasted sales with an aggregate notional volume of 1.6 million tonnes. Such financial contracts may include futures, forwards and options. Included in this total are 1.3 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, 0.6 million tonnes will settle during the nine months ending December 31, 2022 and 0.7 million tonnes will settle during 2023 at expected average pricing of approximately $84 per tonne (Newcastle index). The Newcastle thermal coal index was $271.06 per tonne on March 31, 2022, and the Company had posted $332.0 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 $134 million and result in comparable unrealized gains or losses.

To reduce exposure to additional margin requirements, the Company converted 0.8 million metric tons of financial hedges into fixed price physical sales over the next 12 months. With these transactions, 1.4 million metric tons remain outstanding with 0.9 million metric tons projected to settle over the remainder of 2022.

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. “Derivatives and Fair Value Measurements” to the accompanying unaudited condensed consolidated financial statements. As of March 31, ~~2021,~~2022, the Company had currency options outstanding with an aggregate notional amount of ~~$575.0~~$705.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending December 31, ~~2021.~~2022. 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 ~~$115~~$160 million for the next twelve months. Based upon the Australian dollar/U.S. dollar exchange rate at March 31, ~~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 ~~$80~~$105 million for the next twelve months.

~~Other Non-Coal Trading Activities —~~ Diesel Fuel Price Risk

~~Diesel Fuel Hedges.~~Previously, the Company managed price risk of the diesel fuel used in its mining activities through the use of derivatives, primarily swaps. As of March 31, ~~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 7595 to 85105 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 March 31, ~~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.~~16. “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.

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

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

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

•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;

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

•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 coal reserves and resources and inaccuracies in its estimates could result in lower than expected revenue, higher than expected costs and decreased profitability;

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

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

•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;

•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 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 future repurchases of its stock is dependent on a number of factors and cannot be assured;

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

•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, ~~2024,~~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 March 31, ~~2021,~~2022, the Company has repurchased 41.5 million shares of its common stock for $1,340.3 million, which included commissions paid of $0.8 million, leaving $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, ~~2024,~~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.

~~Share Relinquishments~~Issuances of Equity Securities

In June 2021, the Company announced an at-the-market equity offering program pursuant to which the Company could offer and sell up to 12.5 million shares of its common stock. The at-the-market equity offering program was further expanded to 32.5 million shares during 2021. The shares are offered and sold pursuant to the Company’s Registration Statement on Form S-3, which was declared effective by the Securities and Exchange Commission on April 23, 2021, as supplemented by prospectus supplements dated June 4, 2021, September 17, 2021, and December 17, 2021 relating to the offer and sale of the shares. Through March 31, 2022, the Company ~~routinely allows employees~~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 three months ended March 31, 2022, leaving approximately 7.7 millions shares available for sale.

On March 7, 2022, the Company entered into an at-the-market equity offering program pursuant to ~~relinquish~~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 ~~pay estimated taxes upon~~ the ~~vesting~~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 ~~restricted stock units~~the shares. During the three months ended March 31, 2022, the Company sold approximately 10.1 million shares for net proceeds of $222.0 million, thereby concluding this at-the-market equity offering program.

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Through March 31, 2022, the Company completed multiple bilateral transactions with holders of the 2022 Notes, the 2025 Notes and the ~~payout~~2024 Peabody Notes in which the Company issued an aggregate 10.0 million shares of ~~performance units that are settled in~~its common stock ~~under its equity incentive plans.~~in exchange for $37.3 million aggregate principal amount of the 2022 Notes, $47.2 million aggregate principal amount of the 2025 Notes and $21.6 million aggregate principal amount of the 2024 Peabody Notes. No bilateral transactions were completed during the three months ended March 31, 2022. The ~~value~~issuance of shares of common stock ~~tendered by employees is determined based~~in exchange for the 2022 Notes, the 2025 Notes and the 2024 Peabody Notes was made in reliance on the ~~closing price~~exemption from registration provided in Section 3(a)(9) under the Securities Act of 1933, based in part on representations of holders of the ~~Company’s common stock~~2022 Notes, the 2025 Notes and the 2024 Peabody Notes, and on the ~~dates~~basis that the exchange was completed with existing holders of the ~~respective relinquishments.~~Company's securities and no commission or other remuneration was paid or given for soliciting the exchange.

Purchases of Equity Securities

The following table summarizes all share purchases for the three months ended March 31, ~~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)
January 1 through January 31, 2021 143,465 $ 2.42 — $ 160.5
February 1 through February 28, 2021 65,244 3.83 — 160.5
March 1 through March 31, 2021 — — — 160.5
Total 208,709 2.86 —


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)
January 1 through January 31, 2022	153,389	$	10.44	—	$	160.5
February 1 through February 28, 2022	20,521	17.43		—	160.5
March 1 through March 31, 2022	—	—		—	160.5
Total	173,910	11.27		—

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

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Item 4. Mine Safety Disclosures.

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

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

Item 6. Exhibits.

See Exhibit Index ~~at page 53 of this report.~~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

~~4.8~~4.1						Indenture, dated as of January 29, 2021, by and among the Co-Issuers, Wilmington Trust, National Association, as trustee, and the Company (on a limited basis, to the extent of its obligations specifically set forth therein) (Incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K/A filed on FebruaryMarch 1, ~~2021).~~

~~4.9~~						~~Indenture dated as of January 29, 2021, by and among~~2022, between Peabody ~~the guarantors party thereto,~~Energy Corporation and Wilmington Trust, National Association, as trustee ~~(Incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K/A filed on February 1, 2021).~~

~~4.10~~						Seventh Supplemental Indenture, dated as of January 8, 2021, by and among the Company and Wilmington Trust, National Association, as trustee (Incorporated by reference to Exhibit 4.3 to the Registrant’s Current Report on Form 8-K/A filed on February 1, 2021).

~~4.11~~						Eighth Supplemental Indenture, dated as of January 29, 2021, by and among the Company and Wilmington Trust, National Association, as trustee (Incorporated by reference to Exhibit 4.4 to the Registrant’s Current Report on Form 8-K/A filed on February 1, 2021).

~~4.12~~						First Supplemental Indenture, dated as of February 3, 2021, by and among the Co-Issuers, Wilmington Trust, National Association, as trustee, and Peabody (on a limited basis, to the extent of its obligations specifically set forth therein) (Incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed on ~~February 5, 2021)~~March 1, 2022).

~~4.13~~4.2						~~First Supplemental Indenture, dated as~~Form of ~~February 3, 2021, by and among Peabody, the guarantors party thereto, and Wilmington Trust, National Association, as trustee (Incorporated by reference to~~3.250% Convertible Senior Notes due 2028 (included in Exhibit ~~4.2 to the Registrant’s Current Report on Form 8-K filed on February 5, 2021)~~4.1).

10.1						~~First~~Eighth Amendment to the Sixth Amended and Restated ~~Transaction Support~~Receivables Purchase Agreement, dated as of January ~~29, 2021, between~~28, 2022, by and among P&L Receivables Company, LLC, Peabody ~~certain subsidiaries of Peabody,~~Energy Corporation, all Committed Purchasers listed on the ~~Revolving Lenders,~~signature pages thereto, all Purchaser Agents listed on the ~~Administrative~~signature pages thereto, all LC Participants listed on the signature pages thereto, PNC Bank, National Association, as Administrator and as LC Bank and PNC Capital Markets LLC, as Structuring Agent ~~and the Consenting Noteholders~~ (Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form ~~8-K/A~~8-K filed on ~~February 1, 2021)~~January 31, 2022).

10.2						Agreement for Irrevocable Standby Letters of Credit, dated as of February 17, 2022, between Peabody and Goldman Sachs Bank USA (Incorporated by reference to Exhibit 10.89 to the Registrant’s Annual Report on Form 10-K filed on February 18, 2022).

10.3						Credit Agreement, dated ~~as of January 29, 2021,~~March 7, 2022, by and among ~~the Co-Issuers, as borrowers,~~ Peabody Energy Corporation, as ~~parent, JPMorgan Chase Bank, N.A.,~~borrower, Goldman Sachs Lending Partners LLC, as administrative agent, and the lenders party thereto (Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form ~~8-K/A~~8-K filed on ~~February 1, 2021)~~March 7, 2022).

~~10.3~~10.4†++						Credit Agreement, dated as of January 29, 2021, among Peabody, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, and the lenders party thereto (Incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K/A filed on February 1, 2021).

~~10.4~~						Amendment No. 8 to Credit Agreement, dated as of January 29, 2021, among Peabody Energy Corporation, the subsidiaries of Peabody Energy Corporation party thereto as reaffirming parties, the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent (as successor to Goldman Sachs Bank USA in its capacity as administrative agent) (Incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K/A filed on February 1, 2021).

10.5*						~~Form of 2021 Service-Based Cash Award Agreement (Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 5, 2021).~~

10.6*						~~Form of Amendment No. 1 to 2021 Service-Based Cash Award Agreement (Incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on March 5, 2021).~~

10.7*						~~Employment Transition~~Commitment Agreement, dated March ~~18, 2021, between~~23, 2022, by and among Peabody ~~Energy Corporation~~Investments Corp., The Prudential Insurance Company of America and ~~Glenn L. Kellow (Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 18, 2021).~~Fiduciary Counselors Inc.

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.

~~Table of Contents~~

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~~

~~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.~~document).

†

Filed herewith.

Portions of this exhibit (indicated therein by asterisk) have been omitted for confidential treatment.

Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the Company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10% of the total assets of the Company and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Securities and Exchange Commission upon request.

Table of Contents

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:

May 5, ~~2021~~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)


	Three Months Ended March 31, 2021
	Total (loss) gain recognized in income		Gain realized in income on derivatives		Unrealized loss recognized in income on derivatives
Financial Instrument
	(Dollars in millions)
Foreign currency option contracts	$	(2.9)	$	4.7	$	(7.6)
Coal contracts related to forecasted sales	8.2		10.0		(1.8)
Coal trading contracts	(0.7)		2.4		(3.1)
Total	$	4.6	$	17.1	$	(12.5)

	Three Months Ended March 31, 2020
	Total loss recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Financial Instrument
	(Dollars in millions)
Foreign currency option contracts	$	(0.9)	$	(1.0)	$	0.1
Coal contracts related to forecasted sales	(8.6)		(6.4)		(2.2)
Coal trading contracts	(0.1)		4.1		(4.2)
Total	$	(9.6)	$	(3.3)	$	(6.3)