PEABODY ENERGY CORP - Quarter Report: 2021 September (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

☑

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

For the quarterly period ended

September 30, 2021

☐

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

For the transition period from ____________ to ____________

Commission File Number: 1-16463

____________________________________________

PEABODY ENERGY CORPORATION

(Exact name of registrant as specified in its charter)


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

701 Market Street,

St. Louis,

Missouri

63101-1826

(Address of principal executive offices)

(Zip Code)

(314) 342-3400

(Registrant’s telephone number, including area code)

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


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

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

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

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

Large accelerated filer ☐ Accelerated filer ☑

Non-accelerated filer ☐ Smaller reporting company ☐

Emerging growth company ☐

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

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

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

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

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			32
Item 3. Quantitative and Qualitative Disclosures About Market Risk			56
Item 4. Controls and Procedures			56
PART II — OTHER INFORMATION
Item 1. Legal Proceedings			56
Item 1A. Risk Factors			56
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			58
Item 4. Mine Safety Disclosures			59

Item 6. Exhibits			60
EXHIBIT INDEX			61
SIGNATURE			62

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions, except per share data)
Revenues	$	679.0	$	671.0	$	2,053.7	$	2,143.9
Costs and expenses
Operating costs and expenses (exclusive of items shown separately below)	649.4		550.9		1,843.4		1,886.7
Depreciation, depletion and amortization	77.9		72.2		223.3		266.5
Asset retirement obligation expenses	14.3		14.3		45.3		46.0
Selling and administrative expenses	21.1		27.2		64.2		77.3
Restructuring charges	1.7		8.1		5.9		31.1
Transaction costs related to joint ventures	—		6.0		—		23.1
Other operating (income) loss:
Net gain on disposals	(25.8)		(2.5)		(28.2)		(10.4)
Asset impairment	—		—		—		1,418.1


(Income) loss from equity affiliates	(15.8)		10.6		(11.4)		25.7
Operating loss	(43.8)		(15.8)		(88.8)		(1,620.2)
Interest expense	45.5		34.9		143.3		102.3
Net gain on early debt extinguishment	(16.0)		—		(31.3)		—
Interest income	(1.4)		(1.6)		(4.2)		(7.1)
Net periodic benefit (credit) costs, excluding service cost	(8.6)		2.8		(26.0)		8.3
Net mark-to-market adjustment on actuarially determined liabilities	—		13.0		—		13.0

Loss from continuing operations before income taxes	(63.3)		(64.9)		(170.6)		(1,736.7)
Income tax (benefit) provision	(3.7)		(0.1)		(10.3)		2.7
Loss from continuing operations, net of income taxes	(59.6)		(64.8)		(160.3)		(1,739.4)
Income (loss) from discontinued operations, net of income taxes	24.3		(2.3)		20.0		(6.8)
Net loss	(35.3)		(67.1)		(140.3)		(1,746.2)

Less: Net income (loss) attributable to noncontrolling interests	8.9		0.1		12.6		(5.1)
Net loss attributable to common stockholders	$	(44.2)	$	(67.2)	$	(152.9)	$	(1,741.1)

Loss from continuing operations:
Basic loss per share	$	(0.60)	$	(0.66)	$	(1.65)	$	(17.76)
Diluted loss per share	$	(0.60)	$	(0.66)	$	(1.65)	$	(17.76)
Net loss attributable to common stockholders:
Basic loss per share	$	(0.38)	$	(0.69)	$	(1.46)	$	(17.83)
Diluted loss per share	$	(0.38)	$	(0.69)	$	(1.46)	$	(17.83)

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Net loss	$	(35.3)	$	(67.1)	$	(140.3)	$	(1,746.2)










Postretirement plans (net of $0.0 tax provisions in each period)	(11.0)		172.3		(33.0)		167.9




Foreign currency translation adjustment	(0.8)		2.5		(1.2)		1.8
Other comprehensive (loss) income, net of income taxes	(11.8)		174.8		(34.2)		169.7
Comprehensive (loss) income	(47.1)		107.7		(174.5)		(1,576.5)

Less: Net income (loss) attributable to noncontrolling interests	8.9		0.1		12.6		(5.1)
Comprehensive (loss) income attributable to common stockholders	$	(56.0)	$	107.6	$	(187.1)	$	(1,571.4)

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS


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

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



Other current assets	223.8		204.7
Total current assets	1,311.3		1,420.3
Property, plant, equipment and mine development, net	2,952.0		3,051.1

Operating lease right-of-use assets	38.4		49.9
Investments and other assets	140.8		140.9
Deferred income taxes	—		4.9
Total assets	$	4,442.5	$	4,667.1

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

Accounts payable and accrued expenses	761.7		745.7
Total current liabilities	821.2		790.6
Long-term debt, less current portion	1,268.7		1,502.9
Deferred income taxes	13.0		35.0
Asset retirement obligations	641.9		650.5
Accrued postretirement benefit costs	402.2		413.2
Operating lease liabilities, less current portion	31.6		42.1
Other noncurrent liabilities	221.6		251.5
Total liabilities	3,400.2		3,685.8
Stockholders’ equity

Preferred Stock — $0.01 per share par value; 100.0 shares authorized, no shares issued or outstanding as of September 30, 2021 and December 31, 2020	—		—
Series Common Stock — $0.01 per share par value; 50.0 shares authorized, no shares issued or outstanding as of September 30, 2021 and December 31, 2020	—		—
Common Stock — $0.01 per share par value; 450.0 shares authorized, 165.3 shares issued and 122.3 shares outstanding as of September 30, 2021 and 140.5 shares issued and 97.8 shares outstanding as of December 31, 2020	1.6		1.4
Additional paid-in capital	3,605.1		3,364.6
Treasury stock, at cost — 43.0 and 42.7 common shares as of September 30, 2021 and December 31, 2020	(1,370.2)		(1,368.9)
Accumulated deficit	(1,426.2)		(1,273.3)
Accumulated other comprehensive income	171.6		205.8
Peabody Energy Corporation stockholders’ equity	981.9		929.6
Noncontrolling interests	60.4		51.7
Total stockholders’ equity	1,042.3		981.3
Total liabilities and stockholders’ equity	$	4,442.5	$	4,667.1

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

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

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


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

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

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


Proceeds from disposal of assets, net of receivables	12.7		15.4

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

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

Distributions to noncontrolling interests	(3.9)		(3.5)

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

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY


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





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




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




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

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

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

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


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

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

See accompanying notes to unaudited condensed consolidated financial statements.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1) Basis of Presentation

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

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

Newly Adopted Accounting Standards

Equity Method Investments. In January 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2020-01, which clarifies the interactions between Accounting Standards Codification (ASC) 321, ASC 323 and ASC 815. The new guidance addresses accounting for the transition into and out of the equity method and measuring certain purchased options and forward contracts to acquire investments. ASU 2020-01 is effective on January 1, 2021 for calendar year-end public companies. The Company adopted the requirements effective January 1, 2021. The adoption of this ASU did not have a material impact on the Company’s consolidated financial statements or disclosures.

Accounting Standards Not Yet Implemented

Reference Rate Reform. In March 2020, ASU 2020-04 was issued, which provides optional guidance for a limited period of time to ease the potential burden on accounting for contract modifications caused by reference rate reform (including reform of the London Interbank Offered Rate (LIBOR) or other reference rate reform). This guidance is effective for all entities as of March 12, 2020 through December 31, 2022. The guidance may be adopted over time as reference rate reform activities occur and should be applied on a prospective basis. The Company is still completing its evaluation of the impact of the guidance and plans to elect optional expedients as reference rate reform activities occur. The Company does not expect the guidance to have a material impact 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, for the Company’s policies regarding “Revenues” and “Accounts receivable, net.”

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Disaggregation of Revenues

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


	Three Months Ended September 30, 2021
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	41.1	$	—	$	247.3	$	181.0	$	—	$	469.4
Export	219.4		—		—		2.2		—		221.6
Total thermal	260.5		—		247.3		183.2		—		691.0
Metallurgical coal

Export	—		176.8		—		—		—		176.8
Total metallurgical	—		176.8		—		—		—		176.8
Other (2)	0.2		2.7		(0.2)		1.4		(192.9)		(188.8)
Revenues	$	260.7	$	179.5	$	247.1	$	184.6	$	(192.9)	$	679.0


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

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


	Nine Months Ended September 30, 2021
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	132.7	$	—	$	724.5	$	487.8	$	—	$	1,345.0
Export	497.7		—		—		3.4		—		501.1
Total thermal	630.4		—		724.5		491.2		—		1,846.1
Metallurgical coal
Domestic	—		2.7		—		—		—		2.7
Export	—		381.1		—		—		—		381.1
Total metallurgical	—		383.8		—		—		—		383.8
Other (2)	0.8		4.2		(0.4)		4.8		(185.6)		(176.2)
Revenues	$	631.2	$	388.0	$	724.1	$	496.0	$	(185.6)	$	2,053.7

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)


	Nine Months Ended September 30, 2020
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining		Corporate and Other (1)		Consolidated
	(Dollars in millions)
Thermal coal
Domestic	$	111.9	$	—	$	736.7	$	501.5	$	—	$	1,350.1
Export	412.9		—		—		—		—		412.9
Total thermal	524.8		—		736.7		501.5		—		1,763.0
Metallurgical coal

Export	—		362.3		—		—		—		362.3
Total metallurgical	—		362.3		—		—		—		362.3
Other (2)	1.3		1.3		0.5		22.6		(7.1)		18.6
Revenues	$	526.1	$	363.6	$	737.2	$	524.1	$	(7.1)	$	2,143.9

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

(2) Other includes revenues from arrangements such as customer contract-related payments associated with volume shortfalls, royalties related to coal lease agreements, sales agency commissions, farm income and property and facility rentals.

The Company recorded revenue related to delivered coal to customers of approximately $923 million and $665 million during the three months ended September 30, 2021 and 2020, respectively, and approximately $2,327 million and $2,093 million during the nine months ended September 30, 2021 and 2020, respectively. Such amounts exclude unrealized and realized gains and losses on derivative contracts related to forecasted sales and certain other revenues unrelated to delivered coal.

Committed Revenue from Contracts with Customers

The Company expects to recognize revenue subsequent to September 30, 2021 of approximately $4.6 billion related to contracts with customers in which volumes and prices per ton were fixed or reasonably estimable at September 30, 2021. Approximately 42% of such amount is expected to be recognized over the next twelve months 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.

Accounts Receivable

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


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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(4) Discontinued Operations

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

Summarized Results of Discontinued Operations

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


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

Liabilities of Discontinued Operations

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


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

Patriot-Related Matters

A significant portion of the liabilities in the table above relate to Patriot. In 2012, Patriot filed voluntary petitions for relief under Chapter 11 of Title 11 of the U.S. Code (the Bankruptcy Code). In 2013, the Company entered into a definitive settlement agreement (2013 Agreement) with Patriot and the United Mine Workers of America (UMWA), on behalf of itself, its represented Patriot employees and its represented Patriot retirees, to resolve all then-disputed issues related to Patriot’s bankruptcy. In May 2015, Patriot again filed voluntary petitions for relief under the Bankruptcy Code in the U.S. District Court for the Eastern District of Virginia and subsequently initiated a process to sell substantially all of its assets to qualified bidders. On October 9, 2015, Patriot’s bankruptcy court entered an order confirming Patriot’s plan of reorganization, which provided, among other things, for the sale of substantially all of Patriot’s assets to two different buyers.

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

By statute, the Company had secondary liability for the black lung liabilities related to Patriot’s workers employed by former subsidiaries of the Company. The Company’s accounting for the black lung liabilities related to Patriot is based on an interpretation of applicable statutes. Management believes that inconsistencies exist among the applicable statutes, regulations promulgated under those statutes and the DOL’s interpretative guidance. The Company has sought clarification from the DOL regarding these inconsistencies. 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 $89.7 million and $90.1 million at September 30, 2021 and December 31, 2020, respectively. While the Company has recorded a liability, it intends to review each claim on a case-by-case basis and contest liability estimates as appropriate. The amount 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 as of September 30, 2021 and December 31, 2020 consisted of the following:


	September 30, 2021		December 31, 2020
	(Dollars in millions)
Materials and supplies	$	98.3	$	102.6
Raw coal	53.5		70.5
Saleable coal	72.7		88.5
Total	$	224.5	$	261.6

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

(6) Equity Method Investments

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

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

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 September 30, 2021, the revolving loan limit was $160 million Australian dollars and the Revolving Loans were not fully drawn upon by Middlemount. The Revolving Loans bear interest at 10% per annum and expire on December 31, 2021. The value of the portion of the Revolving Loans due to the Company’s Australian subsidiary was $35.7 million and $46.2 million as of September 30, 2021 and December 31, 2020, respectively, with the decrease during the nine months ended September 30, 2021 primarily attributable to payments made by Middlemount.

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(7) Derivatives and Fair Value Measurements

Derivatives

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

On a limited basis, the Company engages in the direct and brokered trading of coal and freight-related contracts. Except those contracts for which the Company has elected to apply a normal purchases and normal sales exception, all derivative coal trading contracts are accounted for at fair value. The Company had no diesel fuel or interest rate derivatives in place as of September 30, 2021.

Foreign Currency Option Contracts

As of September 30, 2021, the Company had currency options outstanding with an aggregate notional amount of $595.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending June 30, 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 $0.77 to $0.81 over the nine-month period ending June 30, 2022.

Derivative Contracts Related to Forecasted Sales

As of September 30, 2021, the Company held coal derivative contracts related to a portion of its forecasted sales with an aggregate notional volume of 2.9 million tonnes. Such financial contracts may include futures, forwards and options. Included in this total are 2.1 million tonnes related to financial derivatives entered to support the profitability of the Wambo Underground Mine as part of a strategy to extend the mine life through mid-2023. Of this total, 1.4 million tonnes will settle in 2022 and 0.7 million tonnes will settle in 2023 at expected average pricing of approximately $84 per tonne (Newcastle index). The remaining 0.8 million tonnes aggregate notional volume related to other coal financial contracts will settle in the fourth quarter of 2021 (0.2 million tonnes) and 2022 (0.6 million tonnes). Additionally, the Company classifies certain physical forward sales contracts as derivatives for which the normal purchase, normal sales exception does not apply.

During the three months ended September 30, 2021, the Company recorded an unrealized mark-to-market loss of $238.4 million on these coal derivative contracts, which includes approximately $183 million of unrealized mark-to-market losses on financial derivatives, and approximately $55 million on physical forward sales contracts.

Financial Trading Contracts

On a limited basis, the Company may enter coal or freight derivative contracts for trading purposes. Such financial contracts may include futures, forwards and options. The Company held nominal financial trading contracts as of September 30, 2021.

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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.


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

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

The Company generally posts or receives variation margin cash with its clearing broker on the majority of its financial derivatives as market values of the financial derivatives fluctuate. As of September 30, 2021, the Company had posted $239.6 million aggregate margin cash, consisting of $214.3 million variation margin cash and $25.3 million initial margin. As of December 31, 2020, the Company had posted $9.5 million aggregate margin cash, consisting of $6.5 million variation margin cash and $3.0 million initial margin.

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)


		Three Months Ended September 30, 2021
		Total (loss) gain recognized in income		(Loss) gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(1.0)	$	(1.6)	$	0.6
Derivative contracts related to forecasted sales	Revenues	(251.5)		(13.1)		(238.4)
Financial trading contracts	Revenues	0.7		0.7		—
Total		$	(251.8)	$	(14.0)	$	(237.8)

		Three Months Ended September 30, 2020 (1)
		Total gain (loss) recognized in income		Gain (loss) realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	3.9	$	3.2	$	0.7
Derivative contracts related to forecasted sales	Revenues	(3.3)		12.8		(16.1)
Financial trading contracts	Revenues	(0.2)		(0.2)		—
Total		$	0.4	$	15.8	$	(15.4)


		Nine Months Ended September 30, 2021
		Total (loss) gain recognized in income		Gain (loss) realized in income on derivatives		Unrealized (loss) gain recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	(5.3)	$	3.0	$	(8.3)
Derivative contracts related to forecasted sales	Revenues	(292.1)		(28.1)		(264.0)
Financial trading contracts	Revenues	1.4		0.6		0.8
Total		$	(296.0)	$	(24.5)	$	(271.5)

		Nine Months Ended September 30, 2020 (1)
		Total gain (loss) recognized in income		Gain realized in income on derivatives		Unrealized gain (loss) recognized in income on derivatives
Derivative Instrument	Classification
		(Dollars in millions)
Foreign currency option contracts	Operating costs and expenses	$	5.2	$	1.6	$	3.6
Derivative contracts related to forecasted sales	Revenues	19.6		30.9		(11.3)
Financial trading contracts	Revenues	(0.5)		1.9		(2.4)
Total		$	24.3	$	34.4	$	(10.1)

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

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.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Fair Value Measurements

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

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


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

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

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

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

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

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

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

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

•Cash and cash equivalents, 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).

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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


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

Estimated fair value	$	1,236.3	$	987.6

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

The Company had no transfers between Levels 1, 2 and 3 during the three and nine months ended September 30, 2021 and 2020. 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 September 30, 2021 and December 31, 2020 is set forth in the table below:


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

Asset Impairment and Other At-Risk Assets

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

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(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, for the Company’s policies regarding “Leases.”

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

The components of lease expense during the three and nine months ended September 30, 2021 and 2020 were as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Operating lease cost:
Operating lease cost	$	4.6	$	6.3	$	15.3	$	23.3
Short-term lease cost	4.1		10.2		10.5		31.7
Variable lease cost	1.0		1.1		2.0		3.7
Sublease income	(0.5)		—		(1.5)		—
Total operating lease cost	$	9.2	$	17.6	$	26.3	$	58.7

Finance lease cost:
Amortization of right-of-use assets	$	1.6	$	0.8	$	3.7	$	5.2
Interest on lease liabilities	0.8		0.2		2.0		0.5
Total finance lease cost	$	2.4	$	1.0	$	5.7	$	5.7

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Supplemental balance sheet information related to leases at September 30, 2021 and December 31, 2020 was as follows:


	September 30, 2021			December 31, 2020
	(Dollars in millions)
Operating leases:
Operating lease right-of-use assets	$	38.4		$	49.9

Accounts payable and accrued expenses	$	17.0		$	24.5
Operating lease liabilities, less current portion	31.6			42.1
Total operating lease liabilities	$	48.6		$	66.6

Finance leases:
Property, plant, equipment and mine development	$	31.3		$	20.4
Accumulated depreciation	(5.8)			(2.5)
Property, plant, equipment and mine development, net	$	25.5		$	17.9

Current portion of long-term debt	$	15.5		$	21.5
Long-term debt, less current portion	14.9			5.8
Total finance lease liabilities	$	30.4		$	27.3

Weighted average remaining lease term (years)
Operating leases	3.1
Finance leases	6.7

Weighted average discount rate
Operating leases	6.8		%
Finance leases	8.8		%

Supplemental cash flow information related to leases during the three and nine months ended September 30, 2021 and 2020 was as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	4.7	$	6.8	$	17.6	$	26.4
Operating cash flows for finance leases	1.1		0.1		2.9		0.5
Financing cash flows for finance leases	2.8		0.2		5.6		8.1

Right-of-use assets obtained in exchange for lease obligations:
Operating leases	—		0.2		6.8		2.3
Finance leases	1.1		0.5		21.3		1.5

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The Company's leases have remaining lease terms ranging from less than 1 year to 20.3 years, and may include options to extend the terms, as applicable. The contractual maturities of lease liabilities were as follows:


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

(10) Income Taxes

The Company's effective tax rate before remeasurement for the nine months ended September 30, 2021 is based on 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 $3.7 million and $0.1 million for the three months ended September 30, 2021 and 2020, respectively, included a tax benefit of $1.1 million and a tax provision of $1.1 million, respectively, related to the remeasurement of foreign income tax accounts. The Company’s income tax benefit of $10.3 million and income tax provision of $2.7 million for the nine months ended September 30, 2021 and 2020, respectively, included a tax benefit of $1.6 million and a tax provision of $0.4 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 recognized CODI from the Refinancing Transactions of approximately $60 million, and the income will be offset by the Company’s operating losses.

(11) Long-term Debt

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


Debt Instrument (defined below, as applicable)	September 30, 2021		December 31, 2020
	(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	23.1	$	459.0
8.500% Senior Secured Notes due December 2024 (Peabody Notes)	128.8		—
10.000% Senior Secured Notes due December 2024 (Co-Issuer Notes)	193.9		—
6.375% Senior Secured Notes due March 2025 (2025 Notes)	462.4		500.0
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	206.0		—
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	328.7		388.2
Revolving credit facility	—		216.0

Finance lease obligations	30.4		27.3
Less: Debt issuance costs	(45.1)		(42.7)
	1,328.2		1,547.8
Less: Current portion of long-term debt	59.5		44.9
Long-term debt	$	1,268.7	$	1,502.9

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Refinancing Transactions

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

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

The Exchange Offer was accounted for as a debt modification based upon the relative similarity of the present value of the future cash flows of the instruments. As such, no gain or loss was recorded in connection with the Exchange Offer. Fees paid to third parties of $10.6 million were included in “Interest expense” in the accompanying unaudited condensed consolidated statements of operations during the nine months ended September 30, 2021.

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

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

Co-Issuer Notes

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

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

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

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

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

Peabody Notes

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

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

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

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

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

Co-Issuer Term Loans

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

Company LC Agreement

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

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

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

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

6.375% Senior Secured Notes

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

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

Credit Agreement

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

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

In connection with the Revolver Transactions, the Company amended the Credit Agreement to make certain changes in consideration of the Company LC Agreement. After giving effect to the Revolver Transactions, there remain no revolving commitments or revolving loans under the Credit Agreement. Further, all financial covenants specific to the former revolving credit facility under the Credit Agreement were eliminated in connection with the Refinancing Transactions and were not applicable at September 30, 2021. The Company recorded interest expense and fees of $1.4 million during the nine months ended September 30, 2021, and $5.1 million and $10.8 million, during the three and nine months ended September 30, 2020, respectively, related to the revolving loan facility. No interest expense or fees related to the revolving loan facility were recorded during the three months ended September 30, 2021.

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

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

Subsequent Financing Transactions

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

In June 2021, the Company announced an at-the-market equity offering program pursuant to which the Company could offer and sell up to 12.5 million shares of its common stock. During September 2021, the Company announced that it could offer and sell up to an additional 12.5 million shares, for a total of 25.0 million shares authorized through the at-the-market offering program. The shares are offered and sold pursuant to the Company’s Registration Statement on Form S-3, which was declared effective by the Securities and Exchange Commission on April 23, 2021, as supplemented by prospectus supplements dated June 4, 2021 and September 17, 2021, relating to the offer and sale of the shares. During the three and nine months ended September 30, 2021, the Company sold approximately 9.0 million shares and 17.1 million shares, respectively, for net cash proceeds of $112.1 million and $177.2 million, respectively. Between October 1, 2021 and November 2, 2021, the Company settled sales of an additional 3.2 million shares for net proceeds of $43.4 million.

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

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

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

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

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

Finance Lease Obligations

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(12) Pension and Postretirement Benefit Costs

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

Net periodic pension benefit included the following components:


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

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

Annual contributions to the qualified plans are made in accordance with minimum funding standards and the Company’s agreement with the Pension Benefit Guaranty Corporation. Funding decisions also consider certain funded status thresholds defined by the Pension Protection Act of 2006 (generally 80%). As of September 30, 2021, the Company’s qualified plans were expected to be at or above the Pension Protection Act thresholds. The Company is not required to make any contributions to its qualified pension plans in 2021 based on minimum funding requirements and does not expect to make any discretionary contributions in 2021 at this time.

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


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

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

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(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 nine months ended September 30, 2021:


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

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

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

(14) Other Events

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

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

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

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(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 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.

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

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

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(In millions, except per share data)
EPS numerator:
Loss from continuing operations, net of income taxes	$	(59.6)	$	(64.8)	$	(160.3)	$	(1,739.4)
Less: Net income (loss) attributable to noncontrolling interests	8.9		0.1		12.6		(5.1)
Loss from continuing operations attributable to common stockholders	(68.5)		(64.9)		(172.9)		(1,734.3)


Income (loss) from discontinued operations, net of income taxes	24.3		(2.3)		20.0		(6.8)


Net loss attributable to common stockholders	$	(44.2)	$	(67.2)	$	(152.9)	$	(1,741.1)

EPS denominator:


Weighted average shares outstanding — basic and diluted	114.9		97.9		104.9		97.6






Basic and diluted EPS attributable to common stockholders:
Loss from continuing operations	$	(0.60)	$	(0.66)	$	(1.65)	$	(17.76)
Income (loss) from discontinued operations	0.22		(0.03)		0.19		(0.07)
Net loss attributable to common stockholders	$	(0.38)	$	(0.69)	$	(1.46)	$	(17.83)

(16) Financial Instruments and Other Guarantees

The Company is a party to various guarantees and financial instruments that carry off-balance-sheet risk and are not reflected in the accompanying condensed consolidated balance sheets. At September 30, 2021, such instruments included $1,462.4 million of surety bonds and $443.2 million of letters of credit. Such financial instruments provide support for the Company’s reclamation bonding requirements, lease obligations, insurance policies and various other performance guarantees. Reclamation bonding requirements are typically established by statute or under mining permits. At September 30, 2021, the Company’s asset retirement obligations of $710.2 million were supported by surety bonds of $1,293.4 million, as well as letters of credit issued under the Company’s receivables securitization program and the Company LC Agreement. Letters of credit issued at September 30, 2021 which served as collateral for surety bonds in support of asset retirement obligations amounted to $316.1 million.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

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

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

Accounts Receivable Securitization

The Company is party to an accounts receivable securitization agreement (Securitization Program) which expires in April 2022 and provides up to $250.0 million in funding, 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 under the Securitization Program bear interest at LIBOR plus 1.5% 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.

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

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

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.

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(17) Commitments and Contingencies

Commitments

Unconditional Purchase Obligations

As of September 30, 2021, purchase commitments for capital expenditures were $23.4 million, all of which is obligated within the next four years, with $16.2 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. “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.

Contingencies

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

Litigation 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 while the Plaintiffs’ response letter was filed on May 6, 2021. The defendants filed their motion to dismiss on June 7, 2021. The Plaintiffs’ opposition brief to the motion to dismiss was filed on July 22, 2021. The defendants filed their reply to Plaintiff’s opposition on August 23, 2021, completing briefing at this phase of the litigation.

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

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

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other

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

(18) 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 uses Adjusted EBITDA as the primary metric to measure the segments’ operating performance.

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 September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Revenues:
Seaborne Thermal Mining	$	260.7	$	163.0	$	631.2	$	526.1
Seaborne Metallurgical Mining	179.5		78.8		388.0		363.6
Powder River Basin Mining	247.1		264.8		724.1		737.2
Other U.S. Thermal Mining	184.6		179.8		496.0		524.1
Corporate and Other	(192.9)		(15.4)		(185.6)		(7.1)
Total	$	679.0	$	671.0	$	2,053.7	$	2,143.9

Adjusted EBITDA:
Seaborne Thermal Mining	$	104.4	$	35.3	$	204.3	$	118.1
Seaborne Metallurgical Mining	57.4		(27.3)		8.6		(96.1)
Powder River Basin Mining	37.0		78.3		112.6		143.0
Other U.S. Thermal Mining	45.1		51.6		125.6		123.0
Corporate and Other	45.2		(42.5)		21.2		(132.4)
Total	$	289.1	$	95.4	$	472.3	$	155.6

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PEABODY ENERGY CORPORATION

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Loss from continuing operations, net of income taxes	$	(59.6)	$	(64.8)	$	(160.3)	$	(1,739.4)
Depreciation, depletion and amortization	77.9		72.2		223.3		266.5
Asset retirement obligation expenses	14.3		14.3		45.3		46.0
Restructuring charges	1.7		8.1		5.9		31.1
Transaction costs related to joint ventures	—		6.0		—		23.1
Asset impairment	—		—		—		1,418.1


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

Take-or-pay contract-based intangible recognition	(1.0)		(1.5)		(3.2)		(6.8)
Income tax (benefit) provision	(3.7)		(0.1)		(10.3)		2.7
Adjusted EBITDA	$	289.1	$	95.4	$	472.3	$	155.6

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

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

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

Cautionary Notice Regarding Forward-Looking Statements

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

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

When considering these forward-looking statements, you should keep in mind the cautionary statements in this document and in the Company’s other Securities and Exchange Commission (SEC) filings, including, but not limited to, the more detailed discussion of these factors and other factors that could affect its results contained in Item 1A. “Risk Factors” and Item 3. “Legal Proceedings” of its Annual Report on Form 10-K for the year ended December 31, 2020 filed with the SEC on February 23, 2021. These forward-looking statements speak only as of the date on which such statements were made, and the Company undertakes no obligation to update these statements except as required by federal securities laws.

Non-GAAP Financial Measures

The following discussion of the Company’s results of operations includes references to and analysis of Adjusted EBITDA, 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.

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

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

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

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Overview

Peabody is a leading coal producer. In 2020, the Company produced and sold 128.8 million and 132.6 million tons of coal, respectively, from continuing operations. At September 30, 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.

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 September 30, 2021 is set forth in the table below.

The seaborne pricing included in the table below is not necessarily indicative of the pricing the Company realized during the three months ended September 30, 2021 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 quarterly, spot or index basis and seaborne thermal coal contracts on an annual, spot or index basis.

In the U.S., the pricing included in the table below is also not necessarily indicative of the pricing the Company realized during the three months ended September 30, 2021 since the Company generally sells coal under long-term contracts where pricing is determined based on various factors. Such long-term contracts in the U.S. may vary significantly in many respects, including price adjustment features, price reopener terms, coal quality requirements, quantity parameters, permitted sources of supply, treatment of environmental constraints, extension options, force majeure and termination and assignment provisions. Competition from alternative fuels such as natural gas and other fuel sources may also impact the Company’s realized pricing.


	High		Low		Average		September 30, 2021
Premium HCC (1)	$	408.50	$	198.00	$	263.66	$	388.50
Premium PCI coal (1)	255.50		145.25		185.37		242.50
Newcastle index thermal coal (1)	203.20		140.08		166.17		203.20
API 5 thermal coal (1)	111.00		76.09		93.17		111.00
PRB 8,800 Btu/Lb coal (2)	24.00		12.50		14.49		24.00
Illinois Basin 11,500 Btu/Lb coal (2)	66.00		41.00		53.28		66.00

(1) Prices expressed per metric tonne.

(2) Prices expressed per short ton.

Within the global coal industry, supply and demand disruptions were widespread as the coronavirus (COVID-19) pandemic 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. The global coal industry data for the nine months ended September 30, 2021 presented herein may not be indicative of the ultimate impacts of the COVID-19 pandemic given the various levels of response and unknown duration.

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

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Within the seaborne thermal coal market, a combination of tight supplies and elevated demand have driven Newcastle thermal coal pricing to record levels. China’s domestic thermal coal supply remains hampered by heightened safety inspections and mine suspensions, as well as flooding. Thermal electricity generation in China has been strong year-to-date, and the relaxation of China’s import controls combined with tight domestic supply has pushed import demand higher. Both India and China are experiencing rolling power outages, as multi-year low stockpile levels and high coal prices are pushing power plants into load shedding. In Europe, gas supply constraints and low wind generation have pushed standby coal plants to resume operation to help supply strong electricity demand. Despite the strong demand, the supply response has been muted, sending thermal coal prices higher. Heavy rains in Indonesia, rail issues in Russia, production issues in Colombia and hampered domestic supply in China have all combined to pressure the global thermal market.

In the United States, overall electricity demand increased 3% year-over-year, positively impacted by weather and the prior year economic impacts of the COVID-19 pandemic. Electricity generation from thermal coal has notably improved year-over-year as a result of higher natural gas prices and stronger overall electricity demand. This has positively impacted coal’s share of electricity generation, with a rise to approximately 23% for the nine months ended September 30, 2021, while causing natural gas’s share to decline to approximately 37%. Stronger coal use and a limited supply response in coal production has contributed to decreasing coal stockpile levels. Since December 2020, coal inventories have fallen by approximately 54 million tons, a 40% decline. Through the nine months ended September 30, 2021, utility consumption of PRB coal rose approximately 30% compared to the prior year period.

Financing and Surety Transactions

During the fourth quarter of 2020 and the first quarter of 2021, the Company 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.

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

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

Other

During July 2021, the Company executed transactions to sell its closed Millennium and Wilkie Creek Mines, which reduced its closed mine reclamation liabilities and associated costs. Both mines were sold for minimal cash consideration and gains of $26.1 million and $24.6 million, respectively, were recorded in connection with the sales.

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Results of Operations

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

Summary

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

Results from continuing operations, net of income taxes for the three months ended September 30, 2021 increased compared to the same period in the prior year ($5.2 million) primarily due to improved results from equity affiliates ($26.4 million), net gains from asset disposals in the current year ($23.3 million) driven by the sale of the Millennium Mine, net gains on early debt extinguishments in the current year ($16.0 million), net mark-to-market losses on actuarially determined liabilities recorded in the prior year period ($13.0 million) and lower postretirement health care costs ($11.4 million). These favorable variances were offset by higher operating costs and expenses ($98.5 million).

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

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

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

Tons Sold

The following table presents tons sold by operating segment:


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

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Supplemental Financial Data

The following table presents supplemental financial data by operating segment:


	Three Months Ended September 30,				Increase (Decrease)				Nine Months Ended September 30,				Increase (Decrease)
	2021		2020		$		%		2021		2020		$		%
Revenues per Ton - Mining Operations (1)
Seaborne Thermal	$	58.53	$	35.28	$	23.25	66	%	$	49.86	$	38.14	$	11.72	31	%
Seaborne Metallurgical	119.98		71.88		48.10		67	%	99.18		87.16		12.02		14	%
Powder River Basin	10.88		11.26		(0.38)		(3)	%	10.99		11.35		(0.36)		(3)	%
Other U.S. Thermal	40.99		37.20		3.79		10	%	40.20		38.67		1.53		4	%
Costs per Ton - Mining Operations (1)(2)
Seaborne Thermal	$	35.09	$	27.59	$	7.50	27	%	$	33.72	$	29.58	$	4.14	14	%
Seaborne Metallurgical	81.61		96.87		(15.26)		(16)	%	96.98		110.20		(13.22)		(12)	%
Powder River Basin	9.25		7.93		1.32		17	%	9.28		9.15		0.13		1	%
Other U.S. Thermal	30.99		26.52		4.47		17	%	30.02		29.60		0.42		1	%
Adjusted EBITDA Margin per Ton - Mining Operations (1)(2)
Seaborne Thermal	$	23.44	$	7.69	$	15.75	205	%	$	16.14	$	8.56	$	7.58	89	%
Seaborne Metallurgical	38.37		(24.99)		63.36		254	%	2.20		(23.04)		25.24		110	%
Powder River Basin	1.63		3.33		(1.70)		(51)	%	1.71		2.20		(0.49)		(22)	%
Other U.S. Thermal	10.00		10.68		(0.68)		(6)	%	10.18		9.07		1.11		12	%

(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

The following table presents revenues by reporting segment:


	Three Months Ended September 30,				Increase (Decrease) to Revenues				Nine Months Ended September 30,				Increase (Decrease) to Revenues
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	$	260.7	$	163.0	$	97.7	60	%	$	631.2	$	526.1	$	105.1	20	%
Seaborne Metallurgical Mining	179.5		78.8		100.7		128	%	388.0		363.6		24.4		7	%
Powder River Basin Mining	247.1		264.8		(17.7)		(7)	%	724.1		737.2		(13.1)		(2)	%
Other U.S. Thermal Mining	184.6		179.8		4.8		3	%	496.0		524.1		(28.1)		(5)	%
Corporate and Other	(192.9)		(15.4)		(177.5)		(1,153)	%	(185.6)		(7.1)		(178.5)		(2,514)	%
Revenues	$	679.0	$	671.0	$	8.0	1	%	$	2,053.7	$	2,143.9	$	(90.2)	(4)	%

Seaborne Thermal Mining. Segment revenues increased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year due to favorable realized coal pricing (three months, $105.5 million; nine months, $144.8 million), offset by unfavorable volume and mix variances (three months, $7.8 million; nine months, $39.7 million).

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Seaborne Metallurgical Mining. Segment revenues increased during the three months ended September 30, 2021 compared to the same period in the prior year due to favorable realized coal pricing ($67.0 million) and favorable volume and mix variances ($33.7 million). Segment revenues increased during the nine months ended September 30, 2021 compared to the same period in the prior year due to favorable realized coal pricing ($52.3 million), partially offset by unfavorable volume and mix variances ($27.9 million). The unfavorable volume variances resulted from the Shoal Creek Mine being idled through the first nine months of 2021, the Metropolitan Mine being idled through the first quarter of 2021 and the closure of the Millennium Mine during the second quarter of 2020. These unfavorable volume variances were partially offset by improved demand at the Coppabella and Moorvale Mines.

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

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

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

Adjusted EBITDA

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


	Three Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Segment Adjusted EBITDA
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	$	104.4	$	35.3	$	69.1	196	%	$	204.3	$	118.1	$	86.2	73	%
Seaborne Metallurgical Mining	57.4		(27.3)		84.7		310	%	8.6		(96.1)		104.7		109	%
Powder River Basin Mining	37.0		78.3		(41.3)		(53)	%	112.6		143.0		(30.4)		(21)	%
Other U.S. Thermal Mining	45.1		51.6		(6.5)		(13)	%	125.6		123.0		2.6		2	%
Corporate and Other	45.2		(42.5)		87.7		206	%	21.2		(132.4)		153.6		116	%
Adjusted EBITDA (1)	$	289.1	$	95.4	$	193.7	203	%	$	472.3	$	155.6	$	316.7	204	%

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

Seaborne Thermal Mining. Segment Adjusted EBITDA increased during the three months ended September 30, 2021 compared to the same period in the prior year as a result of higher realized net coal pricing ($97.5 million), partially offset by unfavorable mine sequencing impacts ($14.7 million), unfavorable sales volume variances ($5.1 million) and higher commodity pricing ($4.0 million). Segment Adjusted EBITDA increased during the nine months ended September 30, 2021 compared to the same period in the prior year as a result of higher realized net coal pricing ($133.2 million) and cost improvements across the operations and product mix ($21.3 million). The increases were partially offset by unfavorable volume variances ($29.1 million) and unfavorable foreign currency impacts ($28.7 million).

Seaborne Metallurgical Mining. Segment Adjusted EBITDA increased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year due to higher realized net coal pricing (three months, $62.3 million; nine months, $48.8 million), cost improvements at certain mines (three months, $23.1 million; nine months, $71.9 million) and favorable volume variances (three months, $3.5 million; nine months, $19.8 million), offset by unfavorable foreign currency impacts (three months, $2.2 million; nine months, $41.9 million).

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Powder River Basin Mining. Segment Adjusted EBITDA decreased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year due to lower realized net coal pricing (three months, $12.6 million; nine months, $17.7 million), higher costs for materials, services, repairs and labor (three months, $12.6 million; nine months, $16.7 million) and the unfavorable impacts of higher commodity pricing (three months, $8.1 million; nine months, $18.1 million). The decreases were offset by favorable mine sequencing impacts (nine months, $16.5 million).

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

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


	Three Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA				Nine Months Ended September 30,				Increase (Decrease) to Adjusted EBITDA
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Middlemount (1)	$	9.3	$	(11.1)	$	20.4	184	%	$	2.9	$	(27.2)	$	30.1	111	%
Resource management activities (2)	(0.4)		1.0		(1.4)		(140)	%	3.9		9.8		(5.9)		(60)	%
Selling and administrative expenses	(21.1)		(27.2)		6.1		22	%	(64.2)		(77.3)		13.1		17	%
Other items, net (3)	57.4		(5.2)		62.6		1,204	%	78.6		(37.7)		116.3		308	%
Corporate and Other Adjusted EBITDA	$	45.2	$	(42.5)	$	87.7	206	%	$	21.2	$	(132.4)	$	153.6	116	%

(1)Middlemount’s results are before the impact of related changes in deferred tax asset valuation allowance and reserves and amortization of basis difference. Middlemount’s standalone results included (on a 50% attributable basis) aggregate amounts of depreciation, depletion and amortization, asset retirement obligation expenses, net interest expense and income taxes of $17.9 million and $8.6 million during the three months ended September 30, 2021 and 2020, respectively, and $40.7 million and $21.8 million during the nine months ended September 30, 2021 and 2020, respectively.

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

(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 during the three and nine months ended September 30, 2021 compared to the same periods in the prior year was driven by favorable trading results (three months, $27.4 million; nine months, $39.1 million); the gain recognized in the current year on the sale of the Company’s Millennium Mine (three and nine months, $26.1 million) as discussed in Note 14. “Other Events” a favorable variance in Middlemount’s results due to the combined impacts of higher sales pricing, improved production and cost improvements; lower postretirement health care costs (three months, $11.2 million; nine months, $33.6 million) primarily due to changes made to one of the Company’s postretirement health care benefit plans announced in 2020; and lower containment and holding costs for the Company’s North Goonyella Mine (nine months, $15.4 million).

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Loss From Continuing Operations, Net of Income Taxes

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


	Three Months Ended September 30,				Increase (Decrease) to Income				Nine Months Ended September 30,				Increase (Decrease) to Income
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Adjusted EBITDA (1)	$	289.1	$	95.4	$	193.7	203	%	$	472.3	$	155.6	$	316.7	204	%
Depreciation, depletion and amortization	(77.9)		(72.2)		(5.7)		(8)	%	(223.3)		(266.5)		43.2		16	%
Asset retirement obligation expenses	(14.3)		(14.3)		—		—	%	(45.3)		(46.0)		0.7		2	%
Restructuring charges	(1.7)		(8.1)		6.4		79	%	(5.9)		(31.1)		25.2		81	%
Transaction costs related to joint ventures	—		(6.0)		6.0		100	%	—		(23.1)		23.1		100	%
Asset impairment	—		—		—		n.m.		—		(1,418.1)		1,418.1		100	%


Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	6.4		0.5		5.9		1,180	%	8.4		1.6		6.8		425	%
Interest expense	(45.5)		(34.9)		(10.6)		(30)	%	(143.3)		(102.3)		(41.0)		(40)	%
Net gain on early debt extinguishment	16.0		—		16.0		n.m.		31.3		—		31.3		n.m.
Interest income	1.4		1.6		(0.2)		(13)	%	4.2		7.1		(2.9)		(41)	%
Net mark-to-market adjustment on actuarially determined liabilities	—		(13.0)		13.0		100	%	—		(13.0)		13.0		100	%
Unrealized losses on derivative contracts related to forecasted sales	(238.4)		(16.1)		(222.3)		(1,381)	%	(264.0)		(11.3)		(252.7)		(2,236)	%
Unrealized gains (losses) on foreign currency option contracts	0.6		0.7		(0.1)		(14)	%	(8.2)		3.6		(11.8)		(328)	%
Take-or-pay contract-based intangible recognition	1.0		1.5		(0.5)		(33)	%	3.2		6.8		(3.6)		(53)	%
Income tax benefit (provision)	3.7		0.1		3.6		3,600	%	10.3		(2.7)		13.0		481	%
Loss from continuing operations, net of income taxes	$	(59.6)	$	(64.8)	$	5.2	8	%	$	(160.3)	$	(1,739.4)	$	1,579.1	91	%

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


	Three Months Ended September 30,				(Decrease) Increase to Income				Nine Months Ended September 30,				(Decrease) Increase to Income
	2021		2020		$		%		2021		2020		$		%
	(Dollars in millions)								(Dollars in millions)
Seaborne Thermal Mining	$	(25.8)	$	(20.2)	$	(5.6)	(28)	%	$	(73.8)	$	(62.9)	$	(10.9)	(17)	%
Seaborne Metallurgical Mining	(19.6)		(20.0)		0.4		2	%	(53.5)		(65.3)		11.8		18	%
Powder River Basin Mining	(11.9)		(10.9)		(1.0)		(9)	%	(31.8)		(74.4)		42.6		57	%
Other U.S. Thermal Mining	(17.0)		(16.9)		(0.1)		(1)	%	(50.2)		(53.9)		3.7		7	%
Corporate and Other	(3.6)		(4.2)		0.6		14	%	(14.0)		(10.0)		(4.0)		(40)	%
Total	$	(77.9)	$	(72.2)	$	(5.7)	(8)	%	$	(223.3)	$	(266.5)	$	43.2	16	%

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


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

Depreciation, depletion and amortization expense decreased during the nine months ended September 30, 2021 compared to the same period in the prior year primarily due to the impact of the asset impairment recorded at the North Antelope Rochelle Mine during the second quarter of 2020 (nine months, $45.3 million). The decrease in the weighted-average depletion rate per ton for the Seaborne Metallurgical Mining segment during the three and nine months ended September 30, 2021 compared to the same periods in the prior year reflects the volume and mix variances which impacted the Company’s revenues as described above. The decrease in the weighted-average depletion rate per ton for the Powder River Basin Mining segment during the nine months ended September 30, 2021 compared to the same period in the prior year reflects the asset impairment recorded during the second quarter of 2020.

Restructuring Charges. Restructuring charges decreased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year as the result of workforce reductions made across the organization during the prior year.

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

Asset Impairment. During the nine months ended September 30, 2020, the Company recognized $1,418.1 million in aggregate asset impairment charges related to the fair value of its North Antelope Rochelle Mine in its Powder River Basin Mining segment as discussed in Note 8. “Property, Plant, Equipment and Mine Development” to the accompanying unaudited condensed consolidated financial statements.

Interest Expense. Interest expense increased during the three and nine months ended September 30, 2021 compared to the same periods in the prior year as the result of a series of refinancing transactions completed by the Company during the first quarter of 2021 as described in Note 11. “Long-term Debt” to the accompanying unaudited condensed consolidated financial statements.

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

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

Unrealized Losses on Derivative Contracts Related to Forecasted Sales. Unrealized losses primarily relate to mark-to-market activity on derivatives related to 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 increase in the income tax benefit for the three and nine months ended September 30, 2021 compared to the same periods in the prior year was primarily due to differences in forecasted taxable income and an increase in the benefit related to the remeasurement of foreign income tax accounts. Refer to Note 10. “Income Taxes” to the accompanying unaudited condensed consolidated financial statements for additional information.

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Net Loss Attributable to Common Stockholders

The following table presents net loss attributable to common stockholders:


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

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

Diluted Earnings per Share (EPS)

The following table presents diluted EPS:


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

Diluted EPS is commensurate with the changes in results from continuing operations and discontinued operations during that period. Diluted EPS reflects weighted average diluted common shares outstanding of 114.9 million and 97.9 million for the three months ended September 30, 2021 and 2020, respectively, and 104.9 million and 97.6 million for the nine months ended September 30, 2021 and 2020, respectively.

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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 September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Loss from continuing operations, net of income taxes	$	(59.6)	$	(64.8)	$	(160.3)	$	(1,739.4)
Depreciation, depletion and amortization	77.9		72.2		223.3		266.5
Asset retirement obligation expenses	14.3		14.3		45.3		46.0
Restructuring charges	1.7		8.1		5.9		31.1
Transaction costs related to joint ventures	—		6.0		—		23.1
Asset impairment	—		—		—		1,418.1


Changes in deferred tax asset valuation allowance and reserves and amortization of basis difference related to equity affiliates	(6.4)		(0.5)		(8.4)		(1.6)
Interest expense	45.5		34.9		143.3		102.3
Net gain on early debt extinguishment	(16.0)		—		(31.3)		—
Interest income	(1.4)		(1.6)		(4.2)		(7.1)
Net mark-to-market adjustment on actuarially determined liabilities	—		13.0		—		13.0
Unrealized losses on derivative contracts related to forecasted sales	238.4		16.1		264.0		11.3
Unrealized (gains) losses on foreign currency option contracts	(0.6)		(0.7)		8.2		(3.6)
Take-or-pay contract-based intangible recognition	(1.0)		(1.5)		(3.2)		(6.8)
Income tax (benefit) provision	(3.7)		(0.1)		(10.3)		2.7
Total Adjusted EBITDA	$	289.1	$	95.4	$	472.3	$	155.6

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 September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Dollars in millions)
Operating costs and expenses	$	649.4	$	550.9	$	1,843.4	$	1,886.7
Unrealized gains (losses) on foreign currency option contracts	0.6		0.7		(8.2)		3.6
Take-or-pay contract-based intangible recognition	1.0		1.5		3.2		6.8

Net periodic benefit (credit) costs, excluding service cost	(8.6)		2.8		(26.0)		8.3
Total Reporting Segment Costs	$	642.4	$	555.9	$	1,812.4	$	1,905.4

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The following table presents Reporting Segment Costs by reporting segment:


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

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


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

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

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


	Three Months Ended September 30, 2020
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	4.6		1.1		23.6		4.8

Revenues	$	163.0	$	78.8	$	264.8	$	179.8
Reporting Segment Costs	127.7		106.1		186.5		128.2
Adjusted EBITDA	$	35.3	$	(27.3)	$	78.3	$	51.6

Revenues per Ton	$	35.28	$	71.88	$	11.26	$	37.20
Costs per Ton	27.59		96.87		7.93		26.52
Adjusted EBITDA Margin per Ton	$	7.69	$	(24.99)	$	3.33	$	10.68

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

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

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


	Nine Months Ended September 30, 2020
	Seaborne Thermal Mining		Seaborne Metallurgical Mining		Powder River Basin Mining		Other U.S. Thermal Mining
	(Amounts in millions, except per ton data)
Tons sold	13.8		4.2		65.0		13.5

Revenues	$	526.1	$	363.6	$	737.2	$	524.1
Reporting Segment Costs	408.0		459.7		594.2		401.1
Adjusted EBITDA	$	118.1	$	(96.1)	$	143.0	$	123.0

Revenues per Ton	$	38.14	$	87.16	$	11.35	$	38.67
Costs per Ton	29.58		110.20		9.15		29.60
Adjusted EBITDA Margin per Ton	$	8.56	$	(23.04)	$	2.20	$	9.07

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


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

Free Cash Flow	$	(138.1)	$	(191.5)

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. Information regarding the Company’s regulatory matters is outlined in Part I, Item 1. “Business” in its Annual Report on Form 10-K for the year ended December 31, 2020.

Regulatory Matters - U.S.

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

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The CAA requires the 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 (D.C. Circuit). The litigation is currently in abeyance following a motion filed by the EPA to allow for review of the standards.

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

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

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

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

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

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

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

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

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

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

Mercury and Air Toxic Standards (MATS). The EPA published the final MATS rule in the Federal Register in 2012. The MATS rule revised the new source performance standards (NSPS) for NOx, SO2 and PM for new and modified coal-fueled electricity generating plants, and imposed maximum achievable control technology (MACT) emission limits on hazardous air pollutants (HAPs) from new and existing coal-fueled and oil-fueled electric generating plants. MACT standards limit emissions of mercury, acid gas HAPs, non-mercury HAP metals and organic HAPs.

In 2020, the EPA issued a final rule reversing a prior finding and determined that it is not “appropriate and necessary” under the CAA to regulate HAP emissions from coal- and oil-fired power plants. This rule also finalized residual risk and technology review standards for the coal- and oil-fired EGU source category. Both actions were challenged in the D.C. Circuit but this litigation was placed in abeyance. In August 2020, the EPA sent a draft rule to the Office of Management and Budget for review regarding reconsideration of the “appropriate and necessary” finding as well as standards for coal- and oil-fired EGUs.

CWA Definition of “Waters of the United States”. In January 2020 the EPA and the Army Corps of Engineers (Corps) finalized the Navigable Waters Protection Rule to revise the definition of “Waters of the United States” and thereby establish the scope of federal regulatory authority under the CWA. On August 30, 2021, a federal court in Arizona vacated the Navigable Waters Protection Rule, and on September 3, 2021, the EPA and the Corps announced that they had “halted implementation” of the rule nationwide and that they are interpreting “Waters of the United States” consistent with the pre-2015 regulatory framework. The agencies reaffirmed that they are moving forward on two rulemaking proceedings to formally repeal the Navigable Waters Protection Rule and then to build upon the pre-2015 regulatory framework.

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

Regulatory Matters - Australia

The Australian mining industry is regulated by Australian 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 incrementally returned or security released after satisfactory reclamation is progressively completed.

Safe Work Australia (SWA). As part of a broader review of workplace exposure standards, SWA is currently considering a proposal to reduce the time weighted average (TWA) Workplace Exposure Standard (WES) for carbon dioxide (CO2) in Australian coal mines from 12,500 ppm to 5,000 ppm. Currently there is a separate TWA for CO2 in coal mines however SWA proposes to remove this to align with a general industry standard. If implemented, the change has the potential to affect underground mines operating in CO2 rich coal seams, including the primary coal seam of the Company’s Metropolitan Mine. Importantly, a minimum three-year transition period applies for any change to standards.

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

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

Global Climate

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

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

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

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

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

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

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

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

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

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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 has not formally committed to net zero emissions by 2050 with the focus of energy policy on the use of technology to accelerate the development and commercialization of low and zero emissions technologies and driving down electricity prices.

The enactment of future laws or the passage of regulations regarding emissions from the use of coal by the U.S., some of its states or other countries, or other actions to limit such emissions, could result in electricity generators switching from coal to other fuel sources. Further, policies limiting available financing for the development of new coal-fueled power stations could adversely impact the global demand for coal in the future. The potential financial impact on the Company of such future laws, regulations or other policies will depend upon the degree to which any such laws or regulations force electricity generators to diminish their reliance on coal as a fuel source. That, in turn, will depend on a number of factors, including the specific requirements imposed by any such laws, regulations or other policies, the time periods over which those laws, regulations or other policies would be phased in, the state of development and deployment of carbon capture, utilization and storage (CCUS) 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. From time to time, Peabody attempts 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 operations, financial condition or cash flow. The Company does not believe that such analyses reasonably predict the quantitative impact that future laws, regulations or other policies may have on its results of operations, financial condition or cash flows.

Liquidity and Capital Resources

Overview

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

Any future determinations to return capital to stockholders, such as dividends or share repurchases will depend on a variety of factors, including the restrictions set forth under the Company’s debt and surety agreements, its net income or other sources of cash, liquidity position and potential alternative uses of cash, such as internal development projects or acquisitions, as well as economic conditions and expected future financial results. The Company’s ability to early retire debt, declare dividends or repurchase shares in the future will depend on its future financial performance, which in turn depends on the successful implementation of its strategy and on financial, competitive, regulatory, technical and other factors, general economic conditions, demand for and selling prices of coal and other factors specific to its industry, many of which are beyond the Company’s control. The Company has presently suspended the payment of dividends and share repurchases, as discussed in Part II, Item 2. “Unregistered Sales of Equity Securities and Use of Proceeds.”

Liquidity

As of September 30, 2021, the Company’s cash balances totaled $587.0 million, including approximately $265 million held by U.S. subsidiaries, $294 million held by Australian subsidiaries, and the remainder held by other foreign subsidiaries in accounts predominantly domiciled in the U.S. The subsidiaries that conduct the operations of the Wilpinjong Mine held cash of approximately $145 million at September 30, 2021. A significant majority of the cash held by the Company’s foreign subsidiaries is denominated in U.S. dollars. This cash is generally used to support non-U.S. liquidity needs, including capital and operating expenditures in Australia.

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


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

Indebtedness

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


Debt Instrument (defined below, as applicable)	September 30, 2021		December 31, 2020
	(Dollars in millions)
6.000% Senior Secured Notes due March 2022 (2022 Notes)	$	23.1	$	459.0
8.500% Senior Secured Notes due December 2024 (Peabody Notes)	128.8		—
10.000% Senior Secured Notes due December 2024 (Co-Issuer Notes)	193.9		—
6.375% Senior Secured Notes due March 2025 (2025 Notes)	462.4		500.0
Senior Secured Term Loan due 2024 (Co-Issuer Term Loans)	206.0		—
Senior Secured Term Loan due 2025, net of original issue discount (Senior Secured Term Loan)	328.7		388.2
Revolving credit facility	—		216.0

Finance lease obligations	30.4		27.3
Less: Debt issuance costs	(45.1)		(42.7)
	1,328.2		1,547.8
Less: Current portion of long-term debt	59.5		44.9
Long-term debt	$	1,268.7	$	1,502.9

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

Refinancing and Related Transactions

Organizational Realignment

In July and August 2020, 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, the Company’s subsidiary which owns and operates its Wilpinjong Mine in Australia became a subsidiary of the Co-Issuers. The Co-Issuers and the Wilpinjong subsidiary were designated as unrestricted subsidiaries under the Company’s credit agreement (Credit Agreement) and its senior notes’ indenture (the Existing Indenture). In connection with these actions, the Company contributed $100.0 million to the Co-Issuers to provide the Wilpinjong Mine with operating liquidity and address its near-term capital needs.

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Surety Agreement

In November 2020, 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 by the Participating Sureties. In accordance with the Surety Agreement, the Company initially provided $75.0 million of collateral, in the form of letters of credit.

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

Refinancing Transactions

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

Exchange Offer

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

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

Consent Solicitation

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

Revolver Transactions

In connection with the Refinancing Transactions, the Company restructured the revolving loans under the Credit Agreement by (i) making a pay down of revolving loans thereunder in the aggregate amount of $10.0 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.

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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. The Company LC Agreement requires that the Company’s restricted subsidiaries maintain minimum aggregate liquidity of $125.0 million at the end of each quarter through December 31, 2024. As such, liquidity attributable to the Co-Issuers, its subsidiaries and other unrestricted subsidiaries is excluded from the calculation. Liquidity calculated in this manner amounted to $452.2 million at September 30, 2021.

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

Other Debt Financing

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

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

Subsequent Financing Transactions

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

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

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

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Considering the Refinancing Transactions and the subsequent financing transactions described above, the Company expects to incur approximately $190 million of interest expense, including approximately $45 million of non-cash interest expense, during the year ended December 31, 2021.

Refer to Note 11. “Long-term Debt” of the accompanying unaudited condensed consolidated financial statements for additional information related to the subsequent financing transactions described above.

Accounts Receivable Securitization Program

As described in Note 16. “Financial Instruments and Other Guarantees” of the accompanying unaudited condensed consolidated financial statements, the Company entered into an accounts receivable securitization program during 2017 which currently matures in 2022. The Company is in discussions to renew the facility prior to maturity. The program provides for up to $250.0 million in funding, limited to the availability of eligible receivables, accounted for as a secured borrowing. Funding capacity under the program may also be utilized for letters of credit in support of other obligations. At September 30, 2021, the Company had no outstanding borrowings and $133.6 million of letters of credit issued under the program, which were primarily in support of portions of the Company’s reclamation obligations. The Company was not required to post cash collateral under the Securitization Program at September 30, 2021.

Capital Requirements

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

Contractual Obligations

There were no material changes to the Company’s contractual obligations from the information previously provided in Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.

Cash Flows and Free Cash Flow

The following table summarizes the Company’s cash flows for the nine months ended September 30, 2021 and 2020, as reported in the accompanying unaudited condensed consolidated financial statements. Free Cash Flow is a financial measure not recognized in accordance with U.S. GAAP. Refer to the “Reconciliation of Non-GAAP Financial Measures” section above for definitions and reconciliations to the most comparable measures under U.S. GAAP.


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

Net cash used in operating activities	$	(18.4)	$	(32.1)
Net cash used in investing activities	(119.7)		(159.4)

Free Cash Flow	$	(138.1)	$	(191.5)

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

Investing Activities. The decrease in net cash used in investing activities for the nine months ended September 30, 2021 compared to the same period in the prior year was driven by lower capital expenditures ($19.9 million) and lower advances to related parties and joint ventures, on a net basis ($13.4 million).

Financing Activities. The decrease in net cash provided by financing activities for the nine months ended September 30, 2021 compared to the same period in the prior year was driven by $360.0 million of revolving loan and securitization borrowings in the prior year, higher repayments of debt principal ($52.6 million) and payments for deferred financing costs ($22.5 million) in the current year, partially offset by $177.2 million proceeds from the issuance of common stock in the current year.

Off-Balance-Sheet Arrangements

In the normal course of business, the Company is a party to various guarantees and financial instruments that carry off-balance-sheet risk and are not reflected in the accompanying condensed consolidated balance sheets. At September 30, 2021, such instruments included $1,462.4 million of surety bonds and $443.2 million of letters of credit. Such financial instruments provide support for its reclamation bonding requirements, lease obligations, insurance policies and various other performance guarantees. The Company periodically evaluates the instruments for on-balance-sheet treatment based on the amount of exposure under the instrument and the likelihood of required performance. The Company does not expect any material losses to result from these guarantees or off-balance-sheet instruments in excess of liabilities provided for in its condensed consolidated balance sheets.

As of September 30, 2021, 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
	(Dollars in millions)
Surety bonds and bank guarantees	$	1,293.4	$	42.1	$	79.6	$	30.9	$	16.4	$	1,462.4
Letters of credit outstanding under letter of credit facility	205.7		90.4		7.0		5.0		—		308.1
Letters of credit outstanding under accounts receivable securitization program	110.4		18.9		4.4		—		—		133.7
Other letters of credit	—		1.4		—		—		—		1.4
	1,609.5		152.8		91.0		35.9		16.4		1,905.6
Less: Letters of credit in support of surety bonds (4)	(309.7)		(29.8)		—		(1.2)		—		(340.7)
Less: Cash collateral in support of surety bonds (4)	(15.0)		—		—		—		—		(15.0)

Obligations supported, net	$	1,284.8	$	123.0	$	91.0	$	34.7	$	16.4	$	1,549.9

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

(2) Obligations pertain to customer and vendor contracts

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

(4) Serve as collateral for certain surety bonds at the request of surety bond providers. The Company has also posted $7.3 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. “Financial Instruments and Other Guarantees” in the accompanying unaudited condensed consolidated financial statements, the Company is required to provide various forms of financial assurance in support of its mining reclamation obligations in the jurisdictions in which it operates. Such requirements are typically established by statute or under mining permits. Historically, such assurances have taken the form of third-party instruments such as surety bonds, bank guarantees and letters of credit, as well as self-bonding arrangements in the U.S. Self-bonding in the U.S. has become increasingly restricted in recent years, leading to the Company’s increased usage of surety bonds and similar third-party instruments. This change in practice has had an unfavorable impact on its liquidity due to increased collateral requirements and surety and related fees.

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

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

Guarantees and Other Financial Instruments with Off-Balance-Sheet Risk. See Note 16. “Financial Instruments and Other Guarantees” in the Company’s unaudited condensed consolidated financial statements for a discussion 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 and expenses and related disclosure of contingent assets and liabilities. On an ongoing basis, the Company evaluates its estimates. The Company bases its estimates on historical experience and on various other assumptions that it believes are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates.

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

The Company’s critical accounting policies 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. The Company’s critical accounting policies remain unchanged at September 30, 2021.

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.

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 September 30, 2021, the Company had currency options outstanding with an aggregate notional amount of $595.0 million Australian dollars to hedge currency risk associated with anticipated Australian dollar expenditures over the nine-month period ending June 30, 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 $141 million for the next twelve months. Based upon the Australian dollar/U.S. dollar exchange rate at September 30, 2021, the currency option contracts outstanding at that date would limit the Company’s net exposure to a $0.10 unfavorable change in the exchange rate to approximately $125 million for the next twelve months.

Diesel Fuel Price Risk

Previously, the Company managed price risk of the diesel fuel used in its mining activities through the use of derivatives, primarily swaps. As of September 30, 2021, 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 80 to 90 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 million based on its expected usage.

Item 4. Controls and Procedures.

The Company’s disclosure controls and procedures are designed to, among other things, provide reasonable assurance that material information, both financial and non-financial, and other information required under the securities laws to be disclosed is accumulated and communicated to senior management, including its principal executive and financial officers, on a timely basis. The Company’s Chief Executive Officer and Chief Financial Officer have evaluated its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of September 30, 2021, 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. “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 filed with the SEC on February 23, 2021. In addition to the other information set forth in this Quarterly Report, including the information presented in Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” you should carefully consider the risk factors disclosed in the aforementioned filing, which could materially affect the Company’s results of operations, financial condition and liquidity.

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

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

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

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

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

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

•the price of Peabody’s securities may be volatile and could fall below the minimum allowed by New York Stock Exchange listing requirements;

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

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

•the 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 of this Quarterly Report on Form 10-Q.

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 the fourth quarter of 2020, the Company entered into transaction support agreements with its surety bond providers which prohibit the payment of dividends through the earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025) unless otherwise agreed to by the parties to the agreements. 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 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 to $1.5 billion. The Repurchase Program does not have an expiration date and may be discontinued at any time. Through September 30, 2021, 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 with its surety bond providers prohibit share repurchases through the earlier of December 31, 2025, or the maturity of the Credit Agreement (currently March 31, 2025) unless otherwise agreed to by the parties to the agreements. Additionally, restrictive covenants in its credit facility and in the indentures governing its senior secured notes also limit the Company’s ability to repurchase shares. Prior to the suspension, repurchases were made at the Company’s discretion. The specific timing, price and size of purchases depended upon the share price, general market and economic conditions and other considerations, including compliance with various debt agreements in effect at the time the repurchases were made.

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Issuances of Equity Securities

In June 2021, the Company announced an at-the-market equity offering program pursuant to which the Company could offer and sell up to 12.5 million shares of its common stock. During September 2021, the Company announced that it could offer and sell up to an additional 12.5 million shares, for a total of 25.0 million shares authorized through the at-the-market offering program. The shares are offered and sold pursuant to the Company’s Registration Statement on Form S-3, which was declared effective by the Securities and Exchange Commission on April 23, 2021, as supplemented by prospectus supplements dated June 4, 2021 and September 17, 2021, relating to the offer and sale of the shares. During the nine months ended September 30, 2021, the Company sold approximately 17.1 million shares for net cash proceeds of $177.2 million. Between October 1, 2021 and November 2, 2021, the Company settled sales of an additional 3.2 million shares for net proceeds of $43.4 million.

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

Share Relinquishments

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.

Purchases of Equity Securities

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


Period	Total Number of Shares Purchased (1)	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program	Maximum Dollar Value that May Yet Be Used to Repurchase Shares Under the Publicly Announced Program (In millions)
July 1 through July 31, 2021	5,073	$	8.19	—	$	160.5
August 1 through August 31, 2021	—	—		—	160.5
September 1 through September 30, 2021	—	—		—	160.5
Total	5,073	8.19		—

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

Item 4. Mine Safety Disclosures.

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

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

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Item 6. Exhibits.

See Exhibit Index on following pages.

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EXHIBIT INDEX

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


Exhibit No.						Description of Exhibit

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

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

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

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

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

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

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

101.SCH						Inline XBRL Taxonomy Extension Schema Document

101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document

104						Cover Page Interactive Data File formatted as 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.
†						Filed herewith.

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SIGNATURE

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

PEABODY ENERGY CORPORATION

Date:

November 5, 2021

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)