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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

_________________________________________________________________

FORM 10-Q

(Mark One)

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2019

☐ 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: 1-13105

Arch Coal Inc

(Exact name of registrant as specified in its charter)



Delaware		43-0921172
(State or other jurisdiction		(I.R.S. Employer
of incorporation or organization)		Identification Number)



One CityPlace Drive
Suite 300
St. Louis
Missouri		63141
(Address of principal executive offices)		(Zip code)

Registrant’s telephone number, including area code: (314) 994-2700

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



Title of each class	Trading symbol	Name of each exchange on which registered
Common stock, $.01 par value	ARCH	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, 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 ☐

At July 22, 2019, there were 16,262,045 shares of the registrant’s common stock outstanding.

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TABLE OF CONTENTS



		Page
Part 1 FINANCIAL INFORMATION		3
Item 1. Financial Statements		3
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations		29
Item 3. Quantitative and Qualitative Disclosures About Market Risk		44
Item 4. Controls and Procedures		45
Part II OTHER INFORMATION		46
Item 1. Legal Proceedings		46
Item 1A. Risk Factors		46
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		47
Item 4. Mine Safety Disclosures		47
Item 6. Exhibits		48
Signatures		51

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Part I

FINANCIAL INFORMATION

Item 1. Financial Statements.

Arch Coal, Inc. and Subsidiaries Condensed Consolidated Income Statements (in thousands, except per share data)

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(Unaudited)						(Unaudited)
Revenues	$	570,222		$	592,349		$	1,125,405		$	1,167,644
Costs, expenses and other operating
Cost of sales (exclusive of items shown separately below)	451,088			474,388			889,559			929,168
Depreciation, depletion and amortization	26,524			30,549			51,797			60,252
Accretion on asset retirement obligations	5,137			6,993			10,274			13,985
Amortization of sales contracts, net	11			3,248			76			6,299
Change in fair value of coal derivatives and coal trading activities, net	(8,400		)	15,138			(21,381		)	11,724
Selling, general and administrative expenses	25,209			24,756			49,298			50,704
Costs related to proposed joint venture with Peabody Energy	3,018			—			3,018			—
Loss on sale of Lone Mountain Processing, LLC	4,304			—			4,304			—
Other operating income, net	(3,239		)	(7,318		)	(4,889		)	(14,250		)
	503,652			547,754			982,056			1,057,882

Income from operations	66,570			44,595			143,349			109,762
Interest expense, net
Interest expense	(4,375		)	(5,050		)	(8,807		)	(10,445		)
Interest and investment income	2,088			1,552			4,231			2,825
	(2,287		)	(3,498		)	(4,576		)	(7,620		)

Income before nonoperating expenses	64,283			41,097			138,773			102,142

Nonoperating (expenses) income
Non-service related pension and postretirement benefit (costs) credits	(1,336		)	68			(3,102		)	(1,235		)
Net loss resulting from early retirement of debt and debt restructuring	—			(485		)	—			(485		)
Reorganization items, net	(16		)	(740		)	71			(1,041		)
	(1,352		)	(1,157		)	(3,031		)	(2,761		)

Income before income taxes	62,931			39,940			135,742			99,381
Provision for (benefit from) income taxes	91			(3,366		)	161			(3,910		)
Net income	$	62,840		$	43,306		$	135,581		$	103,291

Net income per common share
Basic earnings per common share	$	3.80		$	2.15		$	7.97		$	5.03
Diluted earnings per common share	$	3.53		$	2.06		$	7.45		$	4.81

Weighted average shares outstanding
Basic weighted average shares outstanding	16,543			20,156			17,018			20,529
Diluted weighted average shares outstanding	17,781			21,036			18,190			21,456

Dividends declared per common share	$	0.45		$	0.40		$	0.90		$	0.80

The accompanying notes are an integral part of the condensed consolidated financial statements.

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Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (Loss)

(in thousands)



	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(Unaudited)						(Unaudited)
Net income	$	62,840		$	43,306		$	135,581		$	103,291

Derivative instruments
Comprehensive income (loss) before tax	(2,778		)	(12,293		)	(61		)	(5,736		)
Income tax benefit (provision)	—			—			—			—
	(2,778		)	(12,293		)	(61		)	(5,736		)
Pension, postretirement and other post-employment benefits
Comprehensive income (loss) before tax	2,902			3,653			2,902			3,653
Income tax benefit (provision)	—			—			—			—
	2,902			3,653			2,902			3,653
Available-for-sale securities
Comprehensive income (loss) before tax	274			177			651			(481		)
Income tax benefit (provision)	—			—			—			—
	274			177			651			(481		)

Total other comprehensive income (loss)	398			(8,463		)	3,492			(2,564		)
Total comprehensive income	$	63,238		$	34,843		$	139,073		$	100,727

The accompanying notes are an integral part of the condensed consolidated financial statements.

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Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(in thousands, except per share data)



	June 30,			December 31,
	2019			2018
	(Unaudited)
Assets
Current assets
Cash and cash equivalents	$	232,429		$	264,937
Short term investments	162,656			162,797
Trade accounts receivable	182,824			200,904
Other receivables	32,950			48,926
Inventories	172,841			125,470
Other current assets	56,993			75,749
Total current assets	840,693			878,783
Property, plant and equipment, net	870,889			834,828
Other assets
Equity investments	106,072			104,676
Other noncurrent assets	71,876			68,773
Total other assets	177,948			173,449
Total assets	$	1,889,530		$	1,887,060
Liabilities and Stockholders' Equity
Current Liabilities
Accounts payable	$	138,735		$	128,024
Accrued expenses and other current liabilities	162,741			183,514
Current maturities of debt	13,068			17,797
Total current liabilities	314,544			329,335
Long-term debt	295,263			300,186
Asset retirement obligations	236,317			230,304
Accrued pension benefits	11,649			16,147
Accrued postretirement benefits other than pension	79,992			83,163
Accrued workers’ compensation	173,621			174,303
Other noncurrent liabilities	80,194			48,801
Total liabilities	1,191,580			1,182,239

Stockholders' equity
Common stock, $0.01 par value, authorized 300,000 shares, issued 25,047 shares at June 30, 2019 and December 31, 2018, respectively	250			250
Paid-in capital	728,996			717,492
Retained earnings	647,440			527,666
Treasury stock, 8,785 shares and 7,216 shares at June 30, 2019 and December 31, 2018, respectively, at cost	(725,524		)	(583,883		)
Accumulated other comprehensive income	46,788			43,296
Total stockholders’ equity	697,950			704,821
Total liabilities and stockholders’ equity	$	1,889,530		$	1,887,060

The accompanying notes are an integral part of the condensed consolidated financial statements.

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Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(in thousands)



	Six Months Ended June 30,
	2019			2018
	(Unaudited)
Operating activities
Net income	$	135,581		$	103,291
Adjustments to reconcile to cash provided by operating activities:
Depreciation, depletion and amortization	51,797			60,252
Accretion on asset retirement obligations	10,274			13,985
Amortization of sales contracts, net	76			6,299
Deferred income taxes	13,385			8,730
Employee stock-based compensation expense	11,473			7,992
(Gains) losses on disposals and divestitures, net	(1,415		)	131
Net loss resulting from early retirement of debt and debt restructuring	—			485
Amortization relating to financing activities	1,826			2,170
Changes in:
Receivables	17,871			(20,212		)
Inventories	(47,370		)	(28,245		)
Accounts payable, accrued expenses and other current liabilities	4,497			(11,879		)
Income taxes, net	24,575			11,560
Other	3,336			(9,563		)
Cash provided by operating activities	225,906			144,996
Investing activities
Capital expenditures	(87,854		)	(30,049		)
Minimum royalty payments	(1,125		)	(124		)
Proceeds from disposals and divestitures	1,591			56
Purchases of short term investments	(89,454		)	(110,359		)
Proceeds from sales of short term investments	90,424			105,150
Investments in and advances to affiliates, net	(3,275		)	—
Cash used in investing activities	(89,693		)	(35,326		)
Financing activities
Payments on term loan due 2024	(1,500		)	(1,500		)
Net payments on other debt	(8,845		)	(7,307		)
Debt financing costs	—			(529		)
Net loss resulting from early retirement of debt and debt restructuring	—			(50		)
Dividends paid	(15,264		)	(16,333		)
Purchases of treasury stock	(143,142		)	(115,973		)
Other	30			10
Cash used in financing activities	(168,721		)	(141,682		)
Decrease in cash and cash equivalents, including restricted cash	(32,508		)	(32,012		)
Cash and cash equivalents, including restricted cash, beginning of period	264,937			273,602
Cash and cash equivalents, including restricted cash, end of period	$	232,429		$	241,590

Cash and cash equivalents, including restricted cash, end of period
Cash and cash equivalents	$	232,429		$	241,590
Restricted cash	—			—
	$	232,429		$	241,590

The accompanying notes are an integral part of the condensed consolidated financial statements.

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Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Stockholders’ Equity

(in thousands)



								Treasury			Accumulated Other
	Common		Paid-In		Retained			Stock at			Comprehensive
	Stock		Capital		Earnings			Cost			Income			Total
	(In thousands)
Balances, January 1, 2019	$	250	$	717,492	$	527,666		$	(583,883	)	$	43,296		$	704,821
Dividends on common shares ($0.45/share)	—		—		(8,111		)	—			—			(8,111		)
Total comprehensive income	—		—		72,741			—			3,094			75,835
Employee stock-based compensation	—		5,651		—			—			—			5,651
Purchase of 872,317 shares of common stock under share repurchase program	—		—		—			(78,249		)	—			(78,249		)
Balances at March 31, 2019	$	250	$	723,143	$	592,296		$	(662,132	)	$	46,390		$	699,947

Dividends on common shares ($0.45/share)	—		—		(7,696		)	—			—			(7,696		)
Total comprehensive income	—		—		62,840			—			398			63,238
Employee stock-based compensation	—		5,822		—			—			—			5,822
Purchase of 697,255 shares of common stock under share repurchase program	—		—		—			(63,392		)	—			(63,392		)
Warrants exercised	—		31		—			—			—			31
Balances at June 30, 2019	$	250	$	728,996	$	647,440		$	(725,524	)	$	46,788		$	697,950


Balances, January 1, 2018	$	250	$	700,125	$	247,232		$	(302,109	)	$	20,367		$	665,865
Dividends on common shares ($0.40/share)	—		—		(8,553		)	—			—			(8,553		)
Total comprehensive income	—		—		59,985			—			5,899			65,884
Employee stock-based compensation	—		3,845		—			—			—			3,845
Purchase of 407,091 shares of common stock under share repurchase program	—		—		—			(38,589		)	—			(38,589		)
Warrants exercised	—		10		—			—			—			10
Balances at March 31, 2018	$	250	$	703,980	$	298,664		$	(340,698	)	$	26,266		$	688,462

Dividends on common shares ($0.40/share)	—		—		(8,217		)	—			—			(8,217		)
Total comprehensive income	—		—		43,306			—			(8,463		)	34,843
Employee stock-based compensation	—		4,147		—			—			—			4,147
Purchase of 960,105 shares of common stock under share repurchase program	—		—		—			(78,287		)	—			(78,287		)
Warrants exercised	—		—		—			—			—			—
Balances at June 30, 2018	$	250	$	708,127	$	333,753		$	(418,985	)	$	17,803		$	640,948

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Arch Coal, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(unaudited)

1. Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include the accounts of Arch Coal, Inc. (“Arch Coal”) and its subsidiaries (the “Company”). Unless the context indicates otherwise, the terms “Arch” and the “Company” are used interchangeably in this Quarterly Report on Form 10-Q. The Company’s primary business is the production of thermal and metallurgical coal from surface and underground mines located throughout the United States, for sale to utility, industrial and steel producers both in the United States and around the world. The Company currently operates mining complexes in West Virginia, Illinois, Wyoming and Colorado. All subsidiaries are wholly-owned. Intercompany transactions and accounts 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 for interim financial reporting and U.S. Securities and Exchange Commission regulations. In the opinion of management, all adjustments, consisting of normal, recurring accruals considered necessary for a fair presentation, have been included. Results of operations for the three and six months ended June 30, 2019 are not necessarily indicative of results to be expected for the year ending December 31, 2019. These financial statements should be read in conjunction with the audited financial statements and related notes as of and for the year ended December 31, 2018 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

2. Accounting Policies

Recently Adopted Accounting Guidance

In February 2016, the FASB established Topic 842, Leases, by issuing ASU No. 2016-02, “Leases” which requires lessees to recognize leases on-balance sheet and disclose key information about leasing arrangements. The ASU was subsequently amended by ASU 2018-01, “Land Easements Practical Expedient for Transition to Topic 842;” ASU 2018-10, “Codification Improvements to Topic 842, Leases;” and ASU 2018-11, “Targeted Improvements.” The new standard establishes a right-of-use (“ROU”) model that requires a lessee to recognize an ROU asset and lease liability on the balance sheet for all leases with a term longer than 12 months. The standard also requires a lessee to recognize a single lease cost, calculated so that the cost of the lease is allocated over the term of the lease, on a generally straight line basis. Leases of mineral reserves and related land leases have been exempted from the standard. The Company adopted ASU 2016-02 effective January 1, 2019 and elected the option to not restate comparative periods in transition and also elected the “package of practical expedients” within the standard which permits the Company not to reassess its prior conclusions about lease identification, lease classification and initial direct costs. Additionally, the Company made an election to not separate lease and non-lease components for all leases, and will not use hindsight. Finally, the Company will continue its current policy for accounting for land easements as executory contracts. The adoption of the standard had no impact on the Company’s consolidated income statement or statement of cash flows.

In April 2017, the FASB issued ASU No. 2017-08, “Receivables-Nonrefundable Fees and Other Costs (Subtopic 310-20), Premium Amortization on Purchased Callable Debt Securities.” The new guidance shortens the amortization period for the premium on certain purchased callable debt securities to the earliest call date. The new guidance does not change the accounting for purchased callable debt securities held at a discount. The Company adopted ASU 2017-08 effective January 1, 2019 with no impact on the Company’s financial statements.

In August 2017, the FASB issued ASU No. 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” The new guidance provides targeted improvements to the accounting for hedging activities to better align an entity’s risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedging results. The Company adopted ASU 2017-12 effective January 1, 2019 with no impact on the Company’s financial statements.

In February 2018, the FASB issued ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220)

Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” ASU 2018-02 provides an option to

reclassify stranded tax effects within accumulated other comprehensive income to retained earnings due to the change in the U.S. federal tax rate in the Tax Cuts and Jobs Act of 2017. The Company adopted ASU 2018-02 effective January 1, 2019 with no impact on the Company’s financial statements.

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In June 2018, the FASB issued ASU 2018-07, “Compensation-Stock Compensation (Topic 718), Improvements to Non-employee Share-Based Payment Accounting.” ASU 2018-07 aligns the measurement and classification guidance for share-based payments to non-employees with the guidance for share-based payments to employees. The Company adopted ASU 2018-07 effective January 1, 2019 with no impact on the Company’s financial statements.

In October 2018, the FASB issued ASU 2018-16, “Derivatives and Hedging (Topic 815), Inclusion of the Secured Overnight Financing Rate (SOFR) Overnight Index Swap (OIS) Rate as a Benchmark Interest Rate of Hedge Accounting Purposes.” The Company adopted ASU 2018-16 effective January 1, 2019 with no impact on the Company’s financial statements.

3. Joint Venture with Peabody Energy

On June 18, 2019, Arch Coal, Inc. (“Arch”), entered into a definitive implementation agreement (the “Implementation Agreement”) with Peabody Energy Corporation (“Peabody”), to establish a joint venture that will combine the respective Powder River Basin and Colorado mining operations of Arch and Peabody. Pursuant to the terms of the Implementation Agreement, Arch will hold a 33.5% economic interest, and Peabody will hold a 66.5% economic interest in the joint venture. At the closing, certain of the respective subsidiaries of Arch and Peabody will enter into an Amended and Restated Limited Liability Company Agreement (the “LLC Agreement”) in substantially the form attached as an exhibit to the Implementation Agreement. Under the terms of the LLC Agreement, the governance of the joint venture will be overseen by the joint venture’s board of managers, which will initially be comprised of three representatives appointed by Peabody and two representatives appointed by Arch. Decisions of the board of managers will be determined by a majority vote subject to certain specified matters set forth in the LLC Agreement that will require a supermajority vote. Peabody, or one of its affiliates, will initially be appointed as the operator of the joint venture and will manage the day-to-day operations of the joint venture, subject to the supervision of the joint venture’s board of managers.

Formation of the joint venture is subject to customary closing conditions, including the termination or expiration of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, the receipt of certain other required regulatory approvals and the absence of injunctions or other legal restraints preventing the formation of the joint venture. The obligation of Arch to consummate the transaction is also conditioned upon (a) Arch having obtained consents or refinanced all outstanding indebtedness under Arch’s senior secured term loan facility, Arch’s inventory based revolving credit facility and Arch’s existing accounts receivable securitization facility and (b) Arch having either obtained an exemptive order from the U.S. Securities and Exchange Commission (the “SEC”) or other exemptive determination under the Investment Company Act of 1940 (the “1940 Act”). The obligation of Peabody to consummate the transaction is also conditioned upon Peabody having obtained consents or refinanced all outstanding indebtedness under Peabody’s existing senior secured credit facility, the indenture governing Peabody’s 6.000% Notes due 2022 and 6.375% Notes due 2025 and Peabody’s existing receivables securitization facility. Formation of the joint venture does not require approval of the respective stockholders of either Arch or Peabody.

The Implementation Agreement contains customary representations, warranties and covenants, including an obligation for each of Arch and Peabody to use its best efforts to take all actions necessary to obtain required regulatory approvals, subject to the limitations set forth in the Implementation Agreement.

The Implementation Agreement may be terminated by mutual written agreement of Arch and Peabody and by either Arch or Peabody if, among other things, the closing has not occurred on or prior to December 18, 2020, except that (a) the right to terminate will not be available to a party whose failure to perform any of its obligations under the Implementation Agreement has been a principal cause of or resulted in the failure of the closing to occur on or prior to such date and (b) the right to terminate will not be available to Arch until June 18, 2021 if all closing conditions have been satisfied other than the receipt by Arch of an exemptive order (or other determination) under the 1940 Act.

Additionally, if the closing has not occurred on or prior to June 18, 2020 and all required regulatory approvals have not been obtained, the Implementation Agreement may be terminated by either Arch or Peabody no later than June 29, 2020 following written notice and the payment by the terminating party to the non-terminating party of a termination fee of $40 million; provided, however, that the non-terminating party may elect to extend the Implementation Agreement until September 18, 2020. If the non-terminating party exercises this option to extend, the termination fee payable to the non-terminating party by the terminating party if the closing does not occur on or prior to September 18, 2020 will be reduced to $25 million.

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Except as set forth above, neither party will be required to pay a termination fee if the Implementation Agreement is terminated. If all closing conditions have been satisfied other than the receipt by Arch of an exemptive order (or other determination) under the 1940 Act, Arch will reimburse Peabody for regulatory transaction expenses.

The foregoing description of the Implementation Agreement and the LLC Agreement and the transactions contemplated thereby does not purport to be complete and is subject to, and qualified in its entirety by reference to, the Implementation Agreement, including the form of LLC Agreement attached as an exhibit thereto.

4. Loss on Sale of Lone Mountain Processing, LLC

On September 14, 2017, the Company sold Lone Mountain Processing, LLC and two idled mining companies, Cumberland River Coal LLC and Powell Mountain Energy LLC to Revelation Energy LLC, add recorded a gain on the transaction in that year of $21.3 million. Under the terms of the purchase agreement, Revelation assumed certain traumatic workers compensation claims and pneumoconiosis (occupational disease) benefits. On July 1, 2019, Blackjewel LLC and four affiliates, including Revelation Energy LLC filed for Chapter 11 bankruptcy. As a result of the bankruptcy, the Company has recorded a $4.3 million charge for these claims.

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5. Accumulated Other Comprehensive Income

The following items are included in accumulated other comprehensive income (“AOCI”):



				Pension,
				Postretirement
				and Other						Accumulated
				Post-						Other
	Derivative			Employment			Available-for-			Comprehensive
	Instruments			Benefits			Sale Securities			Income
	(In thousands)
Balance at December 31, 2018	$	3,328		$	40,311		$	(343	)	$	43,296
Unrealized gains	3,072			3,331			666			7,069
Amounts reclassified from AOCI	(3,133		)	(429		)	(15		)	(3,577		)
Balance at June 30, 2019	$	3,267		$	43,213		$	308		$	46,788

The following amounts were reclassified out of AOCI:



	Three Months Ended June 30,				Six Months Ended June 30,
Details About AOCI Components	2019		2018		2019		2018		Line Item in the Condensed Consolidated Statement of Operations
(In thousands)
Coal hedges	$	1,743	$	—	$	2,104	$	—	Revenues
Interest rate hedges	514		348		1,029		488		Interest expense
	—		—		—		—		Provision for (benefit from) income taxes
	$	2,257	$	348	$	3,133	$	488	Net of tax

Pension, postretirement and other post-employment benefits
Pension settlement	429		1,371		429		1,371		Non-service related pension and postretirement benefit (costs) credits
	—		—		—		—		Provision for (benefit from) income taxes
	$	429	$	1,371	$	429	$	1,371	Net of tax

Available-for-sale securities	$	15	$	16	$	15	$	16	Interest and investment income
	—		—		—		—		Provision for (benefit from) income taxes
	$	15	$	16	$	15	$	16	Net of tax

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6. Inventories

Inventories consist of the following:



	June 30,		December 31,
	2019		2018
	(In thousands)
Coal	$	83,432	$	40,982
Repair parts and supplies	89,409		84,488
	$	172,841	$	125,470

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $1.4 million at June 30, 2019 and $0.6 million at December 31, 2018.

7. Investments in Available-for-Sale Securities

The Company has invested in marketable debt securities, primarily highly liquid U.S. Treasury securities and investment grade corporate bonds. These investments are held in the custody of a major financial institution. These securities are classified as available-for-sale securities and, accordingly, the unrealized gains and losses are recorded through other comprehensive income.

The Company’s investments in available-for-sale marketable securities are as follows:



	June 30, 2019
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
U.S. government and agency securities	$	58,283	$	94	$	—		$	58,377	$	58,377	$	—
Corporate notes and bonds	104,066		247		(34		)	104,279		104,279		—
Total Investments	$	162,349	$	341	$	(34	)	$	162,656	$	162,656	$	—



	December 31, 2018
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
U.S. government and agency securities	$	100,003	$	11	$	(126	)	$	99,888	$	99,888	$	—
Corporate notes and bonds	63,137		4		(232		)	62,909		62,909		—
Total Investments	$	163,140	$	15	$	(358	)	$	162,797	$	162,797	$	—

The aggregate fair value of investments with unrealized losses that were owned for less than a year was $25.2 million and $115.2 million at June 30, 2019 and December 31, 2018, respectively. The aggregate fair value of investments with unrealized losses that were owned for over a year was $0.0 million and $32.4 million at June 30, 2019 and December 31, 2018, respectively. The unrealized losses in the Company’s portfolio at June 30, 2019 are the result of normal market fluctuations. The Company does not currently intend to sell these investments before recovery of their amortized cost base.

The debt securities outstanding at June 30, 2019 have maturity dates ranging from the third quarter of 2019 through the fourth quarter of 2020. The Company classifies its investments as current based on the nature of the investments and their availability to provide cash for use in current operations.

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8. Derivatives

Interest rate risk management

The Company has entered into interest rate swaps to reduce the variability of cash outflows associated with interest payments on its variable rate term loan. These swaps have been designated as cash flow hedges. For additional information on these arrangements, see Note 10, “Debt and Financing Arrangements,” in the Condensed Consolidated Financial Statements.

Diesel fuel price risk management

The Company is exposed to price risk with respect to diesel fuel purchased for use in its operations. The Company anticipates purchasing approximately 40 to 47 million gallons of diesel fuel for use in its operations annually. To protect the Company’s cash flows from increases in the price of diesel fuel for its operations, the Company uses forward physical diesel purchase contracts, purchased heating oil call options and New York Mercantile Exchange (“NYMEX”) gulf coast diesel swaps and options. At June 30, 2019, the Company had protected the price on the majority of its expected diesel fuel purchases for the remainder of 2019 with approximately 10 million gallons of heating oil call options with an average strike price of $2.34 per gallon and 12 million gallons of NYMEX gulf coast diesel swaps at an average price of approximately $1.91 per gallon. Additionally, the Company has protected approximately 22% of its expected 2020 purchases using gulf coast diesel call options with an average strike price of $2.30 per gallon. At June 30, 2019, the Company had outstanding heating oil call options and NYMEX gulf coast swaps and options of approximately 32 million gallons for the purpose of managing the price risk associated with future diesel purchases. These positions are not designated as hedges for accounting purposes, and therefore, changes in the fair value are recorded immediately to earnings.

Coal price risk management positions

The Company may sell or purchase forward contracts, swaps and options in the over-the-counter coal market in order to manage its exposure to coal prices. The Company has exposure to the risk of fluctuating coal prices related to forecasted, index-priced sales or purchases of coal or to the risk of changes in the fair value of a fixed price physical sales contract. Certain derivative contracts may be designated as hedges of these risks.

At June 30, 2019, the Company held derivatives for risk management purposes that are expected to settle in the following years:



(Tons in thousands)	2019	2020	Total
Coal sales	1,540	489	2,029
Coal purchases	772	225	997

The Company has also entered into a minimal quantity of natural gas put options to protect the Company from decreases in natural gas prices, which could impact thermal coal demand. These options are not designated as hedges.

Coal trading positions

The Company may sell or purchase forward contracts, swaps and options in the over-the-counter coal market for trading purposes. The Company is exposed to the risk of changes in coal prices on the value of its coal trading portfolio. The estimated future realization of the value of the trading portfolio is $0.6 million of losses during the remainder of 2019 and $0.5 million of losses during 2020.

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Tabular derivatives disclosures

The Company has master netting agreements with all 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 amounts shown in the table below represent the fair value position of individual contracts, and not the net position presented in the accompanying Condensed Consolidated Balance Sheets. The fair value and location of derivatives reflected in the accompanying Condensed Consolidated Balance Sheets are as follows:



	June 30, 2019								December 31, 2018
Fair Value of Derivatives	Asset			Liability					Asset			Liability
(In thousands)	Derivative			Derivative					Derivative			Derivative
Derivatives Designated as Hedging Instruments
Coal	$	7,728		$	(637	)			$	2,342		$	(805	)

Derivatives Not Designated as Hedging Instruments
Heating oil -- diesel purchases	923			(650		)			532			—
Coal -- held for trading purposes	45,685			(46,807		)			10,329			(10,701		)
Coal -- risk management	33,804			(25,150		)			5,672			(19,579		)
Natural gas	—			—					4			(4		)
Total	$	80,412		$	(72,607	)			$	16,537		$	(30,284	)
Total derivatives	$	88,140		$	(73,244	)			$	18,879		$	(31,089	)
Effect of counterparty netting	(72,594		)	72,594					(17,801		)	17,801
Net derivatives as classified in the balance sheets	$	15,546		$	(650	)	$	14,896	$	1,078		$	(13,288	)	$	(12,210	)



		June 30, 2019			December 31, 2018
Net derivatives as reflected on the balance sheets (in thousands)
Heating oil and coal	Other current assets	$	15,546		$	1,078
Coal	Accrued expenses and other current liabilities	(650		)	(13,288		)
		$	14,896		$	(12,210	)

The Company had a current asset representing cash collateral posted to a margin account for derivative positions primarily related to coal derivatives of $2.1 million and $24.7 million at June 30, 2019 and December 31, 2018, respectively. These amounts are not included with the derivatives presented in the table above and are included in “other current assets” in the accompanying Condensed Consolidated Balance Sheets.

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The effects of derivatives on measures of financial performance are as follows:

Derivatives used in Cash Flow Hedging Relationships (in thousands)

Three Months Ended June 30,



		Gain (Loss) Recognized in Other Comprehensive Income						Gains (Losses) Reclassified from Other Comprehensive Income into Income
		2019			2018			2019		2018
Coal sales	(1)	$	4,010		$	(15,462	)	$	1,743	$	—
Coal purchases	(2)	(340		)	2,705			—		—
Totals		$	3,670		$	(12,757	)	$	1,743	$	—

No ineffectiveness or amounts excluded from effectiveness testing relating to the Company’s cash flow hedging relationships were recognized in the results of operations in the three month periods ended June 30, 2019 and 2018.

Derivatives Not Designated as Hedging Instruments (in thousands)

Three Months Ended June 30,



		Gain (Loss) Recognized
		2019			2018
Coal trading — realized and unrealized	(3)	$	(718	)	$	384
Coal risk management — unrealized	(3)	9,137			(15,505		)
Natural gas trading— realized and unrealized	(3)	(19		)	(17		)
Change in fair value of coal derivatives and coal trading activities, net total		$	8,400		$	(15,138	)

Coal risk management— realized	(4)	$	(881	)	$	(1,649	)
Heating oil — diesel purchases	(4)	$	(1,369	)	$	3,657

____________________________________________________________

Location in statement of operations:

(1) — Revenues

(2) — Cost of sales

(3) — Change in fair value of coal derivatives and coal trading activities, net

(4) — Other operating (income) expense, net

Derivatives used in Cash Flow Hedging Relationships (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized in Other Comprehensive Income						Gains (Losses) Reclassified from Other Comprehensive Income into Income
		2019			2018			2019			2018
Coal sales	(1)	$	9,247		$	(10,231	)	$	2,787		$	—
Coal purchases	(2)	(906		)	2,163			(686		)	—
Totals		$	8,341		$	(8,068	)	$	2,101		$	—

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Derivatives Not Designated as Hedging Instruments (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized
		2019			2018
Coal trading — realized and unrealized	(3)	$	(1,101	)	$	942
Coal risk management — unrealized	(3)	22,562			(12,630		)
Natural gas trading— realized and unrealized	(3)	(80		)	(36		)
Change in fair value of coal derivatives and coal trading activities, net total		$	21,381		$	(11,724	)

Coal risk management— realized	(4)	$	(5,292	)	$	(2,680	)
Heating oil — diesel purchases	(4)	$	(732	)	$	3,675

____________________________________________________________

Location in statement of operations:

(1) — Revenues

(2) — Cost of sales

(3) — Change in fair value of coal derivatives and coal trading activities, net

(4) — Other operating (income) expense, net

Based on fair values at June 30, 2019, amounts on derivative contracts designated as hedge instruments in cash flow hedges to be reclassified from other comprehensive income into earnings during the next twelve months are gains of approximately $5.9 million.

9. Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist of the following:



	June 30,		December 31,
	2019		2018
	(In thousands)
Payroll and employee benefits	$	49,418	$	57,166
Taxes other than income taxes	72,502		75,017
Interest	221		156
Acquired sales contracts	319		570
Workers’ compensation	18,108		20,044
Asset retirement obligations	12,297		13,113
Other	9,876		17,448
	$	162,741	$	183,514

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10. Debt and Financing Arrangements



	June 30,			December 31,
	2019			2018
	(In thousands)
Term loan due 2024 ($293.3 million face value)	$	292,224		$	293,626
Other	21,669			30,449
Debt issuance costs	(5,562		)	(6,092		)
	308,331			317,983
Less: current maturities of debt	13,068			17,797
Long-term debt	$	295,263		$	300,186

Term Loan Facility

In 2017, the Company entered into a senior secured term loan credit agreement (the “Credit Agreement”) in an aggregate principal amount of $300 million (the “Term Loan Debt Facility”) with Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, and the other financial institutions from time to time party thereto (collectively, the “Lenders”). The Term Loan Debt Facility was issued at 99.50% of the face amount and will mature on March 7, 2024. The term loans provided under the Term Loan Debt Facility (the “Term Loans”) are subject to quarterly principal amortization payments in an amount equal to $750,000.

During 2018, the Company entered into the Second Amendment (the “Second Amendment”) to its Credit Agreement. The Second Amendment reduced the interest rate on its Term Loan Debt Facility to, at the option of Arch Coal, either (i) the London interbank offered rate (“LIBOR”) plus an applicable margin of 2.75%, subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 1.75%. The LIBOR floor remains at 1.00%. There is no change to the maturities as a result of the Second Amendment.

The Term Loan Debt Facility is guaranteed by all existing and future wholly owned domestic subsidiaries of the Company (collectively, the “Subsidiary Guarantors” and, together with Arch Coal, the “Loan Parties”), subject to customary exceptions, and is secured by first priority security interests on substantially all assets of the Loan Parties, including 100% of the voting equity interests of directly owned domestic subsidiaries and 65% of the voting equity interests of directly owned foreign subsidiaries, subject to customary exceptions.

The Company has the right to prepay Term Loans at any time, and from time to time, in whole or in part without premium or penalty, upon written notice, except that any prepayment of Term Loans that bear interest at the LIBOR Rate other than at the end of the applicable interest periods therefor shall be made with reimbursement for any funding losses and redeployment costs of the Lenders resulting therefrom.

The Term Loan Debt Facility is subject to certain usual and customary mandatory prepayment events, including 100% of net cash proceeds of (i) debt issuances (other than debt permitted to be incurred under the terms of the Term Loan Debt Facility) and (ii) non-ordinary course asset sales or dispositions, subject to customary thresholds, exceptions and reinvestment rights.

The Term Loan Debt Facility contains customary affirmative covenants and representations.

The Term Loan Debt Facility also contains customary negative covenants, which, among other things, and subject to certain exceptions, include restrictions on (i) indebtedness, (ii) liens, (iii) liquidations, mergers, consolidations and acquisitions, (iv) disposition of assets or subsidiaries, (v) affiliate transactions, (vi) creation or ownership of certain subsidiaries, partnerships and joint ventures, (vii) continuation of or change in business, (viii) restricted payments, (ix) prepayment of subordinated and junior lien indebtedness, (x) restrictions in agreements on dividends, intercompany loans and granting liens on the collateral, (xi) loans and investments, (xii) sale and leaseback transactions, (xiii) changes in organizational documents and fiscal year and (xiv) transactions with respect to bonding subsidiaries. The Term Loan Debt Facility does not contain any financial maintenance covenants.

The Term Loan Debt Facility contains customary events of default, subject to customary thresholds and exceptions, including, among other things, (i) nonpayment of principal and nonpayment of interest and fees, (ii) a material inaccuracy of a representation or warranty at the time made, (iii) a failure to comply with any covenant, subject to customary grace periods in the case of certain affirmative covenants, (iv) cross-events of default to indebtedness of at least $50 million, (v) cross-events of

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default to surety, reclamation or similar bonds securing obligations with an aggregate face amount of at least $50 million, (vi) uninsured judgments in excess of $50 million, (vii) any loan document shall cease to be a legal, valid and binding agreement, (viii) uninsured losses or proceedings against assets with a value in excess of $50 million, (ix) certain ERISA events, (x) a change of control or (xi) bankruptcy or insolvency proceedings relating to the Company or any material subsidiary of the Company.

Accounts Receivable Securitization Facility

In 2018, the Company extended and amended its existing trade accounts receivable securitization facility provided to Arch Receivable Company, LLC, a special-purpose entity that is a wholly owned subsidiary of Arch Coal (“Arch Receivable”) (the “Extended Securitization Facility”), which supports the issuance of letters of credit and requests for cash advances. The amendment to the Extended Securitization Facility maintained the $160 million borrowing capacity and extended the maturity date to the date that is three years after the Securitization Facility Closing Date. Additionally, the amendment provided the Company the opportunity to use credit insurance to increase the pool of eligible receivables for borrowing. Pursuant to the Extended Securitization Facility, Arch Receivable also agreed to a revised schedule of fees payable to the administrator and the providers of the Extended Securitization Facility.

The Extended Securitization Facility will terminate at the earliest of (i) three years from the Securitization Facility Closing Date, (ii) if the Liquidity (defined in the Extended Securitization Facility and consistent with the definition in the Inventory Facility) is less than $175 million for a period of 60 consecutive days, the date that is the 364th day after the first day of such 60 consecutive day period, and (iii) the occurrence of certain predefined events substantially consistent with the existing transaction documents. Under the Extended Securitization Facility, Arch Receivable, Arch Coal and certain of Arch Coal’s subsidiaries party to the Extended Securitization Facility have granted to the administrator of the Extended Securitization Facility a first priority security interest in eligible trade accounts receivable generated by such parties from the sale of coal and all proceeds thereof. As of June 30, 2019, letters of credit totaling $15.7 million were outstanding under the facility with $86.5 million available for borrowings.

Inventory-Based Revolving Credit Facility

In 2017, the Company and certain subsidiaries of Arch Coal entered into a senior secured inventory-based revolving credit facility in an aggregate principal amount of $40 million (the “Inventory Facility”) with Regions Bank (“Regions”) as administrative agent and collateral agent, as lender and swingline lender (in such capacities, the “Lender”) and as letter of credit issuer. Availability under the Inventory Facility is subject to a borrowing base consisting of (i) 85% of the net orderly liquidation value of eligible coal inventory, (ii) the lesser of (x) 85% of the net orderly liquidation value of eligible parts and supplies inventory and (y) 35% of the amount determined pursuant to clause (i), and (iii) 100% of Arch Coal’s Eligible Cash (defined in the Inventory Facility), subject to reduction for reserves imposed by Regions.

In 2018, the Company and certain subsidiaries of Arch Coal amended and extended the Inventory Facility by increasing the facility size by $10 million, bringing the total aggregate amount available to $50 million, subject to borrowing base calculations described above.

The commitments under the Inventory Facility will terminate on the date that is the earliest to occur of (i) the date, if any, that is 364 days following the first day that Liquidity (defined in the Inventory Facility and consistent with the definition in the Extended Securitization Facility (as defined below)) is less than $250 million for a period of 60 consecutive days and (ii) the date, if any, that is 60 days following the maturity, termination or repayment in full of the Extended Securitization Facility.

Revolving loan borrowings under the Inventory Facility bear interest at a per annum rate equal to, at the option of Arch Coal, either the base rate or the London interbank offered rate plus, in each case, a margin ranging from 2.00% to 2.50% (in the case of LIBOR loans) and 1.00% to 1.50% (in the case of base rate loans) determined using a Liquidity-based grid. Letters of credit under the Inventory Facility are subject to a fee in an amount equal to the applicable margin for LIBOR loans, plus customary fronting and issuance fees.

All existing and future direct and indirect domestic subsidiaries of Arch Coal, subject to customary exceptions, will either constitute co-borrowers under or guarantors of the Inventory Facility (collectively with Arch Coal, the “Loan Parties”). The Inventory Facility is secured by first priority security interests in the ABL Priority Collateral (defined in the Inventory Facility) of the Loan Parties and second priority security interests in substantially all other assets of the Loan Parties, subject to customary exceptions (including an exception for the collateral that secures the Extended Securitization Facility).

Arch Coal has the right to prepay borrowings under the Inventory Facility at any time and from time to time in whole or in

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part without premium or penalty, upon written notice, except that any prepayment of such borrowings that bear interest at the LIBOR rate other than at the end of the applicable interest periods therefore shall be made with reimbursement for any funding losses and redeployment costs of the Lender resulting therefrom.

The Inventory Facility is subject to certain usual and customary mandatory prepayment events, including non-ordinary course asset sales or dispositions, subject to customary thresholds, exceptions (including exceptions for required prepayments under Arch Coal’s term loan facility) and reinvestment rights.

The Inventory Facility contains certain customary affirmative and negative covenants; events of default, subject to customary thresholds and exceptions; and representations, including certain cash management and reporting requirements that are customary for asset-based credit facilities. The Inventory Facility also includes a requirement to maintain Liquidity equal to or exceeding $175 million at all times. As of June 30, 2019, letters of credit totaling $35.6 million were outstanding under the facility with $14.4 million available for borrowings.

Interest Rate Swaps

The Company has entered into a series of interest rate swaps to fix a portion of the LIBOR interest rate within the term loan. The interest rate swaps qualify for cash flow hedge accounting treatment and as such, the change in the fair value of the interest rate swaps is recorded on the Company’s Condensed Consolidated Balance Sheet as an asset or liability with the effective portion of the gains or losses reported as a component of accumulated other comprehensive income and the ineffective portion reported in earnings. As interest payments are made on the term loan, amounts in accumulated other comprehensive income will be reclassified into earnings through interest expense to reflect a net interest on the term loan equal to the effective yield of the fixed rate of the swap plus 2.75% which is the spread on the revised LIBOR term loan. In the event that an interest rate swap is terminated prior to maturity, gains or losses in accumulated other comprehensive income will remain deferred and be reclassified into earnings in the periods which the hedged forecasted transaction affects earnings.

Below is a summary of the Company’s outstanding interest rate swap agreements designated as hedges as of June 30, 2019:



Notional Amount (in millions)	Effective Date	Fixed Rate	Receive Rate	Expiration Date

$250.0	June 28, 2019	2.025%	1-month LIBOR	June 30, 2020
$200.0	June 30, 2020	2.249%	1-month LIBOR	June 30, 2021
$100.0	June 30, 2021	2.315%	1-month LIBOR	June 30, 2023

The fair value of the interest rate swaps at June 30, 2019 is a liability of $2.6 million which is recorded within Other noncurrent liabilities with the offset to accumulated other comprehensive income on the Company’s Condensed Consolidated Balance Sheet. The Company realized $0.5 million and $1.0 million of gains during the three and six months ended June 30, 2019 related to settlements of the interest rate swaps which was recorded to interest expense on the Company’s Condensed Consolidated Income Statements. The interest rate swaps are classified as level 2 within the fair value hierarchy.

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11. Income Taxes

A reconciliation of the statutory federal income tax provision at the statutory rate to the actual provision for (benefit from) income taxes follows:



	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In thousands)
Income tax provision at statutory rate	$	13,216		$	8,387		$	28,506		$	20,870
Percentage depletion allowance	(3,457		)	(2,488		)	(7,764		)	(7,095		)
State taxes, net of effect of federal taxes	831			583			1,843			1,337
Change in valuation allowance	(11,292		)	(7,317		)	(23,805		)	(17,956		)
Current expense associated with uncertain tax positions	844			792			1,437			2,181
Other, net	(51		)	(3,323		)	(56		)	(3,247		)
Provision for (benefit from) income taxes	$	91		$	(3,366	)	$	161		$	(3,910	)

12. Fair Value Measurements

The hierarchy of fair value measurements assigns a level to fair value measurements based on the inputs used in the respective valuation techniques. The levels of the hierarchy, as defined below, give the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs.

· Level 1 is defined as observable inputs such as quoted prices in active markets for identical assets. Level 1 assets include U.S. Treasury securities, and coal swaps and futures that are submitted for clearing on the New York Mercantile Exchange.

· Level 2 is defined as observable inputs other than Level 1 prices. These include quoted prices for similar assets or liabilities in an active market, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. The Company’s level 2 assets and liabilities include U.S. government agency securities, coal commodity contracts and interest rate swaps with fair values derived from quoted prices in over-the-counter markets or from prices received from direct broker quotes.

· Level 3 is defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. These include the Company’s commodity option contracts (coal, natural gas and heating oil) valued using modeling techniques, such as Black-Scholes, that require the use of inputs, particularly volatility, that are rarely observable. Changes in the unobservable inputs would not have a significant impact on the reported Level 3 fair values at June 30, 2019.

The table below sets forth, by level, the Company’s financial assets and liabilities that are recorded at fair value in the accompanying Condensed Consolidated Balance Sheet:



	June 30, 2019
	Total		Level 1		Level 2		Level 3
	(In thousands)
Assets:
Investments in marketable securities	$	162,656	$	58,377	$	104,279	$	—
Derivatives	15,378		13,883		740		755
Total assets	$	178,034	$	72,260	$	105,019	$	755
Liabilities:
Derivatives	$	3,048	$	—	$	3,048	$	—

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The Company’s contracts with its counterparties allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default or termination. For classification purposes, the Company records the net fair value of all the positions with these counterparties as a net asset or liability. Each level in the table above displays the underlying contracts according to their classification in the accompanying Condensed Consolidated Balance Sheet, based on this counterparty netting.

The following table summarizes the change in the fair values of financial instruments categorized as Level 3.



	Three Months Ended June 30, 2019			Six Months Ended June 30, 2019
	(In thousands)
Balance, beginning of period	$	851		$	532
Realized and unrealized gains recognized in earnings, net	(398		)	(542		)
Purchases	537			1,000
Issuances	—			—
Settlements	(235		)	(235		)
Ending balance	$	755		$	755

Net unrealized losses of $1.4 million and $1.1 million were recognized in the Condensed Consolidated Income Statements within Other operating income, net during the three and six months ended June 30, 2019, respectively, related to Level 3 financial instruments held on June 30, 2019.

Fair Value of Long-Term Debt

At June 30, 2019 and December 31, 2018, the fair value of the Company’s debt, including amounts classified as current, was $314.6 million and $318.6 million, respectively. Fair values are based upon observed prices in an active market, when available, or from valuation models using market information, which fall into Level 2 in the fair value hierarchy.

13. Earnings per Common Share

The Company computes basic net income per share using the weighted average number of common shares outstanding during the period. Diluted net income per share is computed using the weighted average number of common shares and the effect of potentially dilutive securities outstanding during the period. Potentially dilutive securities may consist of warrants, restricted stock units or other contingently issuable shares. The dilutive effect of outstanding warrants, restricted stock units and other contingently issuable shares is reflected in diluted earnings per share by application of the treasury stock method.

The following table provides the basis for basic and diluted earnings per share by reconciling the denominators of the computations:



	Three Months Ended June 30,		Six Months Ended June 30,
	2019	2018	2019	2018
	(In thousands)
Weighted average shares outstanding:
Basic weighted average shares outstanding	16,543	20,156	17,018	20,529
Effect of dilutive securities	1,238	880	1,172	927
Diluted weighted average shares outstanding	17,781	21,036	18,190	21,456

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14. Workers Compensation Expense

The Company is liable under the Federal Mine Safety and Health Act of 1969, as subsequently amended, to provide for pneumoconiosis (occupational disease) benefits to eligible employees, former employees and dependents. The Company currently provides for federal claims principally through a self-insurance program. The Company is also liable under various state workers’ compensation statutes for occupational disease benefits. The occupational disease benefit obligation represents the present value of the actuarially computed present and future liabilities for such benefits over the employees’ applicable years of service.

In addition, the Company is liable for workers’ compensation benefits for traumatic injuries which are calculated using actuarially-based loss rates, loss development factors and discounted based on a risk free rate. Traumatic workers’ compensation claims are insured with varying retentions/deductibles, or through state-sponsored workers’ compensation programs.

Workers’ compensation expense consists of the following components:



	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In thousands)
Self-insured occupational disease benefits:
Service cost	$	1,669	$	1,860	$	3,338	$	3,720
Interest cost⁽¹⁾	1,354		1,194		2,708		2,389
Total occupational disease	$	3,023	$	3,054	$	6,046	$	6,109
Traumatic injury claims and assessments	2,410		2,188		4,554		5,199
Total workers’ compensation expense	$	5,433	$	5,242	$	10,600	$	11,308

(1) In accordance with the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” these costs are recorded within Nonoperating expenses in the Condensed Consolidated Income Statements on the line item “Non-service related pension and postretirement benefit costs.”

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15. Employee Benefit Plans

The following table details the components of pension benefit costs (credits):



	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In thousands)
Interest cost⁽¹⁾	$	2,259		$	2,270		$	4,517		$	4,541
Expected return on plan assets⁽¹⁾	(2,724		)	(3,080		)	(5,447		)	(6,161		)
Pension settlement⁽¹⁾	(429		)	(1,371		)	(429		)	(1,371		)
Net benefit credit	$	(894	)	$	(2,181	)	$	(1,359	)	$	(2,991	)

The following table details the components of other postretirement benefit costs:



	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In thousands)
Service cost	$	120	$	139	$	240	$	279
Interest cost⁽¹⁾	877		919		1,753		1,837
Net benefit cost	$	997	$	1,058	$	1,993	$	2,116

16. Commitments and Contingencies

The Company accrues for costs related to contingencies when a loss is probable and the amount is reasonably determinable. Disclosure of contingencies is included in the financial statements when it is at least reasonably possible that a material loss or an additional material loss in excess of amounts already accrued may be incurred.

In addition, the Company is a party to numerous other claims and lawsuits with respect to various matters. The ultimate resolution of any such legal matter could result in outcomes which may be materially different from amounts the Company has accrued for such matters. The Company believes it has recorded adequate reserves for these matters.

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17. Segment Information

The Company’s reportable business segments are based on two distinct lines of business, metallurgical and thermal, and may include a number of mine complexes. The Company manages its coal sales by market, not by individual mining complex. Geology, coal transportation routes to customers, and regulatory environments also have a significant impact on the Company’s marketing and operations management. Mining operations are evaluated based on Adjusted EBITDA, per-ton cash operating costs (defined as including all mining costs except depreciation, depletion, amortization, accretion on asset retirement obligations, and pass-through transportation expenses), and on other non-financial measures, such as safety and environmental performance. Adjusted EBITDA is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDA are significant in understanding and assessing the Company’s financial condition. Therefore, Adjusted EBITDA should not be considered in isolation, nor as an alternative to net income, income from operations, cash flows from operations or as a measure of our profitability, liquidity or performance under generally accepted accounting principles. The Company uses Adjusted EBITDA to measure the operating performance of its segments and allocate resources to the segments. Furthermore, analogous measures are used by industry analysts and investors to evaluate the Company’s operating performance. Investors should be aware that the Company’s presentation of Adjusted EBITDA may not be comparable to similarly titled measures used by other companies. The Company reports its results of operations primarily through the following reportable segments: Powder River Basin (PRB) segment containing the Company’s primary thermal operations in Wyoming; the Metallurgical (MET) segment, containing the Company’s metallurgical operations in West Virginia, and the Other Thermal segment containing the Company’s supplementary thermal operations in Colorado, Illinois, and West Virginia.

Operating segment results for the three and six months ended June 30, 2019 and 2018, are presented below. The Company measures its segments based on “adjusted earnings before interest, taxes, depreciation, depletion, amortization, accretion on asset retirements obligations, and nonoperating expenses (Adjusted EBITDA).” Adjusted EBITDA does not reflect mine closure or impairment costs, since those are not reflected in the operating income reviewed by management. The Corporate, Other and Eliminations grouping includes these charges, as well as the change in fair value of coal derivatives and coal trading activities, net; corporate overhead; land management activities; other support functions; and the elimination of intercompany transactions.

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	PRB		MET		Other Thermal		Corporate, Other and Eliminations			Consolidated
	(in thousands)
Three Months Ended June 30, 2019
Revenues	$	210,149	$	261,245	$	98,205	$	623		$	570,222
Adjusted EBITDA	14,696		101,936		10,922		(21,990		)	105,564
Depreciation, depletion and amortization	4,880		17,343		3,689		612			26,524
Accretion on asset retirement obligation	3,135		531		603		868			5,137
Total assets	236,527		605,657		136,899		910,447			1,889,530
Capital expenditures	13,209		31,150		3,211		1,138			48,708

Three Months Ended June 30, 2018
Revenues	$	229,878	$	259,032	$	99,814	$	3,625		$	592,349
Adjusted EBITDA	26,491		86,657		11,842		(39,605		)	85,385
Depreciation, depletion and amortization	8,304		18,018		3,701		526			30,549
Accretion on asset retirement obligation	4,885		469		565		1,074			6,993
Total assets	379,613		551,012		134,319		884,469			1,949,413
Capital expenditures	3,065		11,899		2,559		3,073			20,596

Six Months Ended June 30, 2019
Revenues	$	422,878	$	514,507	$	184,183	$	3,837		$	1,125,405
Adjusted EBITDA	35,279		193,470		17,041		(32,972		)	212,818
Depreciation, depletion and amortization	9,745		33,725		7,124		1,203			51,797
Accretion on asset retirement obligation	6,271		1,061		1,207		1,735			10,274
Total assets	236,527		605,657		136,899		910,447			1,889,530
Capital expenditures	13,623		62,374		9,461		2,396			87,854

Six Months Ended June 30, 2018
Revenues	$	475,306	$	497,379	$	191,334	$	3,625		$	1,167,644
Adjusted EBITDA	53,993		170,399		27,510		(61,604		)	190,298
Depreciation, depletion and amortization	16,727		35,003		7,536		986			60,252
Accretion on asset retirement obligation	9,771		937		1,130		2,147			13,985
Total assets	379,613		551,012		134,319		884,469			1,949,413
Capital expenditures	3,763		17,728		3,765		4,793			30,049

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A reconciliation of net income to adjusted EBITDA follows:



	Three Months Ended June 30,					Six Months Ended June 30,
	2019		2018			2019			2018
	(In thousands)
Net income	$	62,840	$	43,306		$	135,581		$	103,291
Provision for (benefit from) income taxes	91		(3,366		)	161			(3,910		)
Interest expense, net	2,287		3,498			4,576			7,620
Depreciation, depletion and amortization	26,524		30,549			51,797			60,252
Accretion on asset retirement obligations	5,137		6,993			10,274			13,985
Amortization of sales contracts, net	11		3,248			76			6,299
Loss on sale of Lone Mountain Processing, LLC	4,304		—			4,304			—
Net loss resulting from early retirement of debt and debt restructuring	—		485			—			485
Non-service related pension and postretirement benefit costs	1,336		(68		)	3,102			1,235
Reorganization items, net	16		740			(71		)	1,041
Costs associated with proposed joint venture with Peabody Energy	3,018		—			3,018			—
Adjusted EBITDA	$	105,564	$	85,385		$	212,818		$	190,298

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18. Revenue Recognition

ASC 606-10-50-5 requires that entities disclose disaggregated revenue information in categories (such as type of good or service, geography, market, type of contract, etc.) that depict how the nature, amount, timing, and uncertainty of revenue and cash flow are affected by economic factors. ASC 606-10-55-89 explains that the extent to which an entity’s revenue is disaggregated depends on the facts and circumstances that pertain to the entity’s contracts with customers and that some entities may need to use more than one type of category to meet the objective for disaggregating revenue.

In general, the Company’s business segmentation is aligned according to the nature and economic characteristics of its coal and customer relationships and provides meaningful disaggregation of each segment’s results. The company has further disaggregated revenue between North America and Seaborne revenues which depicts the pricing and contract differences between the two. North America revenue is characterized by contracts with a term of one year or longer and typically the pricing is fixed; whereas Seaborne revenue generally is derived by spot or short term contracts with an indexed based pricing mechanism.



	PRB		MET		Other Thermal		Corporate, Other and Eliminations		Consolidated
	(in thousands)
Three Months Ended June 30, 2019
North America revenues	$	210,149	$	54,896	$	47,885	$	623	$	313,553
Seaborne revenues	—		206,349		50,320		—		256,669

Total revenues	$	210,149	$	261,245	$	98,205	$	623	$	570,222

Three Months Ended June 30, 2018
North America revenues	$	229,035	$	38,323	$	40,547	$	3,625	$	311,530
Seaborne revenues	843		220,709		59,267		—		280,819

Total revenues	$	229,878	$	259,032	$	99,814	$	3,625	$	592,349

Six Months Ended June 30, 2019
North America revenues	$	422,878	$	99,562	$	94,414	$	3,837	$	620,691
Seaborne revenues	—		414,945		89,769		—		504,714

Total revenues	$	422,878	$	514,507	$	184,183	$	3,837	$	1,125,405

Six Months Ended June 30, 2018
North America revenues	$	473,395	$	68,001	$	84,214	$	3,625	$	629,235
Seaborne revenues	1,911		429,378		107,120		—		538,409

Total revenues	$	475,306	$	497,379	$	191,334	$	3,625	$	1,167,644

As of June 30, 2019, the Company has outstanding performance obligations for the remainder of 2019 of 38.9 million tons of fixed price contracts and 4.9 million tons of variable price contracts. Additionally, the Company has outstanding performance obligations beyond 2019 of approximately 64.3 million tons of fixed price contracts and 5.7 million tons of variable price contracts.

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19. Leases

The Company has operating leases for mining equipment, office equipment and office space with remaining lease terms ranging from less than 1 year to approximately 8 years. Some of these leases include both lease and non-lease components which are accounted for as a single lease component as the Company has elected the practical expedient to combine these components for all leases. As most of the leases do not provide an implicit rate, the Company calculated the right-of-use assets and lease liabilities using its’ secured incremental borrowing rate at the lease commencement date. The Company currently does not have any finance leases outstanding.

Information related to leases was as follows:



	Three Months Ended June 30, 2019
	(In thousands)
Operating lease information:
Operating lease cost	$	916
Operating cash flows from operating leases	869
Weighted average remaining lease term in years	5.45
Weighted average discount rate	5.5		%

Future minimum lease payments under non-cancellable leases as of June 30, 2019 were as follows:



Year	Amount
	(In thousands)
2019	$	2,101
2020	3,616
2021	3,367
2022	3,292
2023	3,261
Thereafter	11,153
Total minimum lease payments	$	26,790
Less imputed interest	(5,012		)

Total operating lease liability	$	21,778

As reflected on balance sheet:
Accrued expenses and other current liabilities	$	2,909
Other noncurrent liabilities	18,869

Total operating lease liability	$	21,778

At June 30, 2019, the Company had a $21.1 million right-of-use operating lease asset recorded within “Other noncurrent assets” on the Condensed Consolidated Balance Sheet.

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Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

Cautionary Notice Regarding Forward-Looking Statements

This report contains “forward-looking statements” - that is, statements related to future, not past, events. In this context, forward-looking statements often address our expected future business and financial performance, and often contain words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” or “will.” Forward-looking statements by their nature address matters that are, to different degrees, uncertain. For us, particular uncertainties arise from our emergence from Chapter 11 bankruptcy protection; changes in the demand for our coal by the electric generation and steel industries; from legislation and regulations relating to the Clean Air Act and other environmental initiatives; from competition within our industry and with producers of competing energy sources; from our ability to successfully acquire or develop coal reserves; from operational, geological, permit, labor and weather-related factors, from the Tax Cuts and Jobs Act and other tax reforms; from the effects of foreign and domestic trade policies, actions or disputes; from fluctuations in the amount of cash we generate from operations which could impact, among other things, our ability to pay dividends or repurchase shares in accordance with our announced capital allocation plan; from our ability to successfully integrate the operations that we acquire; from our ability to complete the joint venture transaction with Peabody Energy Corporation (“Peabody”) in a timely manner, including obtaining regulatory approvals and satisfying other closing conditions; from our ability to achieve the expected synergies from the joint venture; from our ability to successfully integrate the operations of certain mines in the joint venture; and from numerous other matters of national, regional and global scale, including those of a political, economic, business, competitive or regulatory nature. These uncertainties may cause our actual future results to be materially different than those expressed in our forward-looking statements. We do not undertake to update our forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by law. For a more detailed description of some of the risks and uncertainties that may affect our future results, you should see the “Risk Factors” in Item 1A of our Annual Report on

Form 10-K for the year ended December 31, 2018 and subsequent Form 10-Q filings.

Overview

Our results for the second quarter of 2019 benefited from relatively strong metallurgical coal markets, while domestic and international thermal coal markets faced adversity. Metallurgical coal markets remained strong, but began to weaken in the second quarter of 2019, as global economic growth continued but moderated, and supply constraints remained supportive of international coking coal prices. Looking forward, slowing economic growth in some regions, particularly Europe, and related declining margins for steel producers, are impacting coking coal prices. We believe both Atlantic and Pacific coking coal markets currently remain well balanced; however, weakening steel production in the European region has precipitated some softening of the Atlantic coking coal market. Some additional coking coal supply has come back into the market from existing and formerly idled operations, and some new development is occurring. At the same time, normal depletion and disruptive events have removed some significant production sources. Overall, global capital investment in new production capacity appears to be limited. We believe that this long term limited capital investment in the industry has increased the sensitivity of global coking coal markets to supply disruptions. In isolation, steel tariffs appear to have had little direct impact on coking coal pricing or demand to date. The longer term implications of these steel tariffs and the wider renegotiations of trade agreements, for coking coal markets and the global economy as a whole, remain less certain.

Demand for domestic thermal coal in the current quarter continued to be negatively impacted by flooding in the High Plains and Midwest that disrupted rail transportation. Powder River Basin and Colorado coals, in particular, were impacted by these disruptions. Furthermore, current quarter natural gas pricing was meaningfully lower than during the prior year quarter due to increased production and higher levels of storage for the competing fuel. Generator coal stockpiles remain near historically normal levels considering seasonality and based on days of burn. International thermal coal market pricing continued to decline throughout the current quarter, reaching uneconomic levels for effectively all of our thermal operations. However, the forward positions we entered into in previous periods allowed our operations to continue to economically ship coal into these markets throughout the current quarter.

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Recent Events

On June 18, 2019, we entered into a definitive implementation agreement (the “Implementation Agreement”) with Peabody, to establish a joint venture that will combine the companies’ Powder River Basin and Colorado mining operations. Pursuant to the terms of the Implementation Agreement, we will hold a 33.5% economic interest and Peabody will hold a 66.5% economic interest in the joint venture. At the closing of the joint venture transaction, we will enter into an Amended and Restated Limited Liability Company Agreement (the “LLC Agreement”). Under the terms of the LLC Agreement, the governance of the joint venture will be overseen by the joint venture’s board of managers, which will initially be comprised of three representatives appointed by Peabody and two representatives appointed by us. Decisions of the board of managers will be determined by a majority vote subject to certain specified matters set forth in the LLC Agreement that will require a supermajority vote. Peabody, or one of its affiliates, will initially be appointed as the operator of the joint venture and will manage the day-to-day operations of the joint venture, subject to the supervision of the joint venture’s board of managers.

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Results of Operations

Three Months Ended June 30, 2019 and 2018

Revenues. Our revenues include sales to customers of coal produced at our operations and coal purchased from third parties. Transportation costs are included in cost of coal sales and amounts billed by us to our customers for transportation are included in revenues.

Coal Sales. The following table summarizes information about our coal sales during the three months ended June 30, 2019 and 2018:



	Three Months Ended June 30,
	2019		2018		(Decrease) / Increase
	(In thousands)
Coal sales	$	570,222	$	592,349	$	(22,127	)
Tons sold	20,976		22,952		(1,976		)

On a consolidated basis, coal sales in the second quarter of 2019 were approximately $22.1 million or 3.7% less than in the second quarter of 2018, while tons sold decreased approximately 2.0 million tons or 8.6%. Coal sales from Metallurgical operations increased approximately $2.2 million on increased pricing, largely offset by decreased shipment volume. Powder River Basin coal sales decreased approximately $19.7 million primarily due to decreased volume, and Other Thermal coal sales decreased approximately $1.6 million due to decreased volume partially offset by increased pricing. See discussion in “Operational Performance” for further information about segment results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the three months ended June 30, 2019 and 2018:



	Three Months Ended June 30,
	2019			2018			Increase (Decrease) in Net Income
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	451,088		$	474,388		$	23,300
Depreciation, depletion and amortization	26,524			30,549			4,025
Accretion on asset retirement obligations	5,137			6,993			1,856
Amortization of sales contracts, net	11			3,248			3,237
Change in fair value of coal derivatives and coal trading activities, net	(8,400		)	15,138			23,538
Selling, general and administrative expenses	25,209			24,756			(453		)
Costs related to proposed joint venture with Peabody Energy	3,018			—			(3,018		)
Loss on sale of Lone Mountain Processing, LLC	4,304			—			(4,304		)
Other operating income, net	(3,239		)	(7,318		)	(4,079		)
Total costs, expenses and other	$	503,652		$	547,754		$	44,102

Cost of sales. Our cost of sales for the second quarter of 2019 decreased approximately $23.3 million or 4.9% versus the second quarter of 2018. The decrease consists primarily of reductions of approximately $9.2 million in purchased coal costs, $7.4 million in transportation costs, $5.9 million in operating taxes and royalties, and $17.8 million due to a relatively larger build in coal inventories. These cost decreases were partially offset by increases of approximately $4.2 million in repairs and supplies costs, $5.0 million in labor related costs, and $4.4 million in other miscellaneous costs primarily related to increased subsidence mitigation costs. See discussion in “Operational Performance” for further information about segment results.

Depreciation, depletion, and amortization. The decrease in depreciation, depletion, and amortization in the second quarter of 2019 versus the second quarter of 2018 is primarily due to reduced depreciation and development amortization in our Powder River Basin segment.

Accretion on asset retirement obligations. The decrease in accretion on asset retirement obligations in the second quarter of 2019 versus the second quarter of 2018 is related to the significant reduction in our Powder River Basin asset retirement obligation liability at the end of 2018 due to mine plan changes.

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Amortization of sales contracts, net. The decrease in amortization of sales contracts, net in the second quarter of 2019 versus the second quarter of 2018 is primarily related to the value of certain Powder River Basin supply contracts being fully amortized at the end of 2018.

Change in fair value of coal derivatives and coal trading activities, net. The increased benefit in the second quarter of 2019 versus the prior year period is primarily related to mark-to-market gains on coal derivatives that we have entered to hedge our price risk for anticipated international thermal coal shipments. As international thermal markets declined during the current quarter, the market value of these positions increased.

Selling, general and administrative expenses. Selling, general and administrative expenses in the second quarter of 2019 increased versus the second quarter of 2018 due to increased compensation costs.

Loss on sale of Lone Mountain Processing, LLC Our loss on sale of Lone Mountain Processing, LLC in the current period relates to recognition of certain contingent workers’ compensation liabilities, both occupational disease and traumatic, that may accrue to us as a result of the recent bankruptcy filing by Revelation Energy LLC. For further information regarding the loss on sale of Lone Mountain Processing, LLC see Note 4, “Loss on Sale of Lone Mountain Processing, LLC” to the Condensed Consolidated Financial Statements.

Other operating income, net. The decreased benefit from other operating income, net in the second quarter of 2019 versus the second quarter of 2018 consists primarily of reduced income from equity investments (approximately $0.8 million), the unfavorable impact of mark to market movement on heating oil positions (approximately $5.0 million), and reduced third party transloading income (approximately $1.0 million), partially offset by gain on disposition of certain assets (approximately $3.2 million), and the favorable impact of coal derivative settlements (approximately $0.8 million).

Nonoperating Expense. The following table summarizes our nonoperating expense during the three months ended June 30, 2019 and 2018:



	Three Months Ended June 30,
	2019			2018			Increase (Decrease) in Net Income
	(In thousands)
Non-service related pension and postretirement benefit (costs) credits	$	(1,336	)	$	68		$	(1,404	)
Net loss resulting from early retirement of debt and debt restructuring	—			(485		)	485
Reorganization items, net	(16		)	(740		)	724
Total nonoperating expense	$	(1,352	)	$	(1,157	)	$	(195	)

Nonoperating expenses increased in the second quarter of 2019 versus the second quarter of 2018 due to an increase in non-service related pension and postretirement benefit costs partially offset by costs associated with the repricing of our term loan and from Chapter 11 reorganization costs in the prior year period.

Provision for (Benefit from) income taxes. The following table summarizes our Provision for (Benefit from) income taxes during the three months ended June 30, 2019 and 2018:



	Three Months Ended June 30,
	2019		2018			Increase (Decrease) in Net Income
	(In thousands)
Provision for (Benefit from) income taxes	$	91	$	(3,366	)	$	(3,457	)

See Note 11, “Income Taxes,” to the Condensed Consolidated Financial Statements for a reconciliation of the statutory federal income tax provision (benefit) at the statutory rate to the actual provision for (benefit from) income taxes.

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Six Months Ended June 30, 2019 and 2018

Coal Sales. The following table summarizes information about our coal sales during the six months ended June 30, 2019 and 2018:



	Six Months Ended June 30,
	2019		2018		(Decrease) / Increase
	(In thousands)
Coal sales	$	1,125,405	$	1,167,644	$	(42,239	)
Tons sold	41,701		46,616		(4,915		)

On a consolidated basis, coal sales in the six months ended June 30, 2019 were approximately $42.2 million or 3.6% less than in the six months ended June 30, 2018, while tons sold decreased approximately 4.9 million tons or 10.5%. Coal sales from Metallurgical operations increased approximately $17.1 million on increased pricing, partially offset by decreased shipment volume. Powder River Basin coal sales decreased approximately $52.4 million primarily due to decreased volume, and Other Thermal coal sales decreased approximately $7.2 million due to decreased volume partially offset by increased pricing. See discussion in “Operational Performance” for further information about segment results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the six months ended June 30, 2019 and 2018:



	Six Months Ended June 30,
	2019			2018			Increase (Decrease) in Net Income
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	889,559		$	929,168		$	39,609
Depreciation, depletion and amortization	51,797			60,252			8,455
Accretion on asset retirement obligations	10,274			13,985			3,711
Amortization of sales contracts, net	76			6,299			6,223
Change in fair value of coal derivatives and coal trading activities, net	(21,381		)	11,724			33,105
Selling, general and administrative expenses	49,298			50,704			1,406
Costs related to proposed joint venture with Peabody Energy	3,018			—			(3,018		)
Loss on sale of Lone Mountain Processing, LLC	4,304			—			(4,304		)
Other operating income, net	(4,889		)	(14,250		)	(9,361		)
Total costs, expenses and other	$	982,056		$	1,057,882		$	75,826

Cost of sales. Our cost of sales for the six months ended June 30, 2019 decreased approximately $39.6 million or 4.3% versus the six months ended June 30, 2018. The decrease consists primarily of reductions of approximately $26.1 million in operating taxes and royalties, $11.9 million in purchased coal costs, and $19.8 million due to a relatively larger build in coal inventories. These cost decreases were partially offset by increases of approximately $9.7 million in labor related costs, $3.6 million in transportation costs, and $4.6 million in other miscellaneous costs primarily related to increased subsidence mitigation costs. See discussion in “Operational Performance” for further information about segment results.

Depreciation, depletion, and amortization. The decrease in depreciation, depletion, and amortization in the six months ended June 30, 2019 versus the six months ended June 30, 2018 is primarily due to reduced depreciation and development amortization in our Powder River Basin segment.

Accretion on asset retirement obligations. The decrease in accretion on asset retirement obligations in the six months ended June 30, 2019 versus the six months ended June 30, 2018 is related to the significant reduction in our Powder River Basin asset retirement obligation liability at the end of 2018 due to mine plan changes.

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Amortization of sales contracts, net. The decrease in amortization of sales contracts, net in the six months ended June 30, 2019 versus the six months ended June 30, 2018 is primarily related to the value of certain Powder River Basin supply contracts being fully amortized at the end of 2018.

Change in fair value of coal derivatives and coal trading activities, net. The increased benefit in the six months ended June 30, 2019 versus the prior year period is primarily related to mark-to-market gains on coal derivatives that we have entered to hedge our price risk for anticipated international thermal coal shipments. As international thermal markets declined during the current six month period, the market value of these positions increased.

Selling, general and administrative expenses. The decrease in selling, general and administrative expenses in the six months ended June 30, 2019 versus the six months ended June 30, 2018 is primarily due to reduced contractor services costs (approximately $1.5 million).

Other operating income, net. The decreased benefit from other operating income, net in the six months ended June 30, 2019 versus the six months ended June 30, 2018 consists primarily of reduced income from equity investments (approximately $3.6 million), the unfavorable impact of mark to market movements on heating oil positions (approximately $4.4 million), and the unfavorable impact of coal derivative settlements in the current period (approximately $2.6 million), partially offset by increased gain on disposition of certain assets (approximately $3.9 million).

Nonoperating Expense. The following table summarizes our nonoperating expense during the six months ended June 30, 2019 and 2018:



	Six Months Ended June 30,
	2019			2018			Increase (Decrease) in Net Income
	(In thousands)
Non-service related pension and postretirement benefit (costs) credits	$	(3,102	)	$	(1,235	)	$	(1,867	)
Net loss resulting from early retirement of debt and debt restructuring	—			(485		)	485
Reorganization items, net	71			(1,041		)	1,112
Total nonoperating expense	$	(3,031	)	$	(2,761	)	$	(270	)

Nonoperating expenses increased slightly in the six months ended June 30, 2019 versus the six months ended June 30, 2018 due to an increase in non-service related pension and postretirement benefit costs partially offset by costs associated with the repricing of our term loan and from Chapter 11 reorganization costs in the prior year period.

Provision for (Benefit from) income taxes. The following table summarizes our Provision for (Benefit from) income taxes during the six months ended June 30, 2019 and 2018:



	Six Months Ended June 30,
	2019		2018			Increase (Decrease) in Net Income
	(In thousands)
Provision for (Benefit from) income taxes	$	161	$	(3,910	)	$	(4,071	)

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Operational Performance

Three Months Ended June 30, 2019 and 2018

Our mining operations are evaluated based on Adjusted EBITDA, per-ton cash operating costs (defined as including all mining costs except depreciation, depletion, amortization, accretion on asset retirements obligations, and pass-through transportation expenses), and on other non-financial measures, such as safety and environmental performance. Adjusted EBITDA is defined as net income attributable to the Company before the effect of net interest expense, income taxes, depreciation, depletion and amortization, the amortization of sales contracts, the accretion on asset retirement obligations and nonoperating expenses. Adjusted EBITDA may also be adjusted for items that may not reflect the trend of future results by excluding transactions that are not indicative of our core operating performance. Adjusted EBITDA is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDA are significant in understanding and assessing our financial condition. Therefore, Adjusted EBITDA should not be considered in isolation, nor as an alternative to net income, income from operations, cash flows from operations or as a measure of our profitability, liquidity or performance under generally accepted accounting principles. Furthermore, analogous measures are used by industry analysts and investors to evaluate the Company’s operating performance. Investors should be aware that our presentation of Adjusted EBITDA may not be comparable to similarly titled measures used by other companies.

The following table shows results by operating segment for the three and six months ended June 30, 2019 and June 30, 2018.



	Three Months Ended June 30,							Six Months Ended June 30,
	2019		2018		Variance			2019		2018		Variance
Powder River Basin
Tons sold (in thousands)	17,149		18,792		(1,643		)	34,289		38,535		(4,246		)
Coal sales per ton sold	$	12.08	$	12.06	$	0.02		$	12.13	$	12.11	$	0.02
Cash cost per ton sold	$	11.29	$	10.66	$	(0.63	)	$	11.14	$	10.72	$	(0.42	)
Cash margin per ton sold	$	0.79	$	1.40	$	(0.61	)	$	0.99	$	1.39	$	(0.40	)
Adjusted EBITDA (in thousands)	$	14,696	$	26,491	$	(11,795	)	$	35,279	$	53,993	$	(18,714	)
Metallurgical
Tons sold (in thousands)	1,892		2,009		(117		)	3,685		3,764		(79		)
Coal sales per ton sold	$	115.87	$	104.38	$	11.49		$	117.01	$	109.78	$	7.23
Cash cost per ton sold	$	62.07	$	61.33	$	(0.74	)	$	64.60	$	64.59	$	(0.01	)
Cash margin per ton sold	$	53.80	$	43.05	$	10.75		$	52.41	$	45.19	$	7.22
Adjusted EBITDA (in thousands)	$	101,936	$	86,657	$	15,279		$	193,470	$	170,399	$	23,071
Other Thermal
Tons sold (in thousands)	1,916		2,036		(120		)	3,602		4,203		(601		)
Coal sales per ton sold	$	39.09	$	36.77	$	2.32		$	38.85	$	36.16	$	2.69
Cash cost per ton sold	$	33.62	$	31.19	$	(2.43	)	$	34.39	$	29.82	$	(4.57	)
Cash margin per ton sold	$	5.47	$	5.58	$	(0.11	)	$	4.46	$	6.34	$	(1.88	)
Adjusted EBITDA (in thousands)	$	10,922	$	11,842	$	(920	)	$	17,041	$	27,510	$	(10,469	)

This table reflects numbers reported under a basis that differs from U.S. GAAP. See the “Reconciliation of Non-GAAP measures” below for explanation and reconciliation of these amounts to the nearest GAAP measures. Other companies may calculate these per ton amounts differently, and our calculation may not be comparable to other similarly titled measures.

Powder River Basin — Adjusted EBITDA for the three and six months ended June 30, 2019 declined versus the three and six months ended June 30, 2018, as a result of a decline in volume versus the prior year periods. This volume decline was greatly exacerbated by the impact of flooding on rail performance discussed in the “Overview” above. Pricing increased slightly as the increase in the percentage of higher quality tons sold from scaling back operations at our lower quality Coal Creek mine more than offset the normal year end roll off and replacement of term contracts that had been executed during stronger thermal coal market environments that generally correlate with periods of higher natural gas pricing. Due to market weakness for lower quality Powder River Basin coal, we decided to reduce operations at our Coal Creek mine rather than pursue uneconomic business. We continue to believe this reduction will last at least through the current year, and the resulting change in the mix of tons sold will put upward pressure on both coal sales per ton sold and cash cost per ton sold. Cash cost per ton sold increased due to the volume decrease, but the increase in cash cost per ton sold was mitigated somewhat by reduced repair costs and the reversion of the Federal Black Lung Excise Tax rate to the pre-1986 rates. The current period

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Federal Black Lung Excise Tax rate for surface mines is $0.25 per ton or 2% of gross selling price on all domestic sales, versus the prior year period rate of $0.55 per ton sold or 4.4% of gross selling price.

Metallurgical — Adjusted EBITDA for the three and six months ended June 30, 2019, increased from the three and six months ended June 30, 2018 due to improvement in pricing, partially offset by a reduction in the volume of tons sold. Cash cost per ton sold increased slightly in the current quarter and was effectively flat for the first six months of the current year. Given our significant exposure to international metallurgical coal pricing through various indexed and negotiated pricing mechanisms, our coal sales per ton sold continued to be supported by strength in international metallurgical coal markets in the current quarter. Tons sold volume declined slightly due to customer delivery schedules for both coking coal and associated thermal coal. Our cash cost per ton sold for the three months ended June 30, 2019 increased due to the decreased sales volume, some inflationary pressure on labor and materials cost, increased operating tax and royalty costs associated with increased pricing, and increased subsidence mitigation costs at our Leer Mine specific to the current quarter. These cost pressures were partially offset by the benefit of increased production volume.

Our Metallurgical segment sold 1.6 million tons of coking coal and 0.3 million tons of associated thermal coal in the three months ended June 30, 2019, compared to 1.7 million tons of coking coal and 0.3 million tons of associated thermal coal in the three months ended June 30, 2018. For the six months ended June 30, 2019, we sold 3.1 million tons of coking coal and 0.6 million tons of associated thermal coal effectively matching the 3.1 million tons of coking coal and 0.6 million tons of associated thermal coal sold in the six months ended June 30, 2018. Longwall operations accounted for approximately 68% of our shipment volume in the three and six months ended June 30, 2019 and 69% of our shipment volume in the three and six months ended June 30, 2018.

Other Thermal — Adjusted EBITDA for the three and six months ended June 30, 2019 decreased versus the three and six months ended June 30, 2018 due to reduced sales volume and increased cash cost of tons sold. Volume decreased in the first six months of the current year primarily due to a planned first quarter reduction at our West Elk operation to accommodate customer delivery schedules and our longwall development requirements, and a reduction at our Coal-Mac operation as higher mining ratios led to a decrease in tons produced. The planned decline in West Elk tons sold volume in the first quarter, which decreased the percentage of tons sold from the lower priced operation, and a year over year increase in pricing at both our West Elk and Coal-Mac operations in the current, quarter drove the increases in coal sales per ton sold in the current three and six month periods. The volume reductions at both West Elk and Coal-Mac resulted in higher cash cost per ton sold.

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Reconciliation of Non-GAAP measures

Segment coal sales per ton sold

Non-GAAP Segment coal sales per ton sold is calculated as segment coal sales revenues divided by segment tons sold. Segment coal sales revenues are adjusted for transportation costs, and may be adjusted for other items that, due to generally accepted accounting principles, are classified in “other income” on the statement of operations, but relate to price protection on the sale of coal. Segment coal sales per ton sold is not a measure of financial performance in accordance with generally accepted accounting principles. We believe segment coal sales per ton sold provides useful information to investors as it better reflects our revenue for the quality of coal sold and our operating results by including all income from coal sales. The adjustments made to arrive at these measures are significant in understanding and assessing our financial condition. Therefore, segment coal sales revenues should not be considered in isolation, nor as an alternative to coal sales revenues under generally accepted accounting principles.



Three Months Ended June 30, 2019	Powder River Basin		Metallurgical		Other Thermal			Idle and Other		Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	210,149	$	261,245	$	98,205		$	623	$	570,222
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		(1,036		)	—		(1,036		)
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—			623		623
Transportation costs	2,924		41,963		24,339			—		69,226
Non-GAAP Segment coal sales revenues	$	207,225	$	219,282	$	74,902		$	—	$	501,409
Tons sold	17,149		1,892		1,916
Coal sales per ton sold	$	12.08	$	115.87	$	39.09

Three Months Ended June 30, 2018	Powder River Basin		Metallurgical		Other Thermal			Idle and Other		Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	229,878	$	259,032	$	99,814		$	3,625	$	592,349
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		1,649			—		1,649
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—			3,625		3,625
Transportation costs	3,176		49,308		23,281			—		75,765
Non-GAAP Segment coal sales revenues	$	226,702	$	209,724	$	74,884		$	—	$	511,310
Tons sold	18,792		2,009		2,036
Coal sales per ton sold	$	12.06	$	104.38	$	36.77

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Six Months Ended June 30, 2019	Powder River Basin		Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	422,878	$	514,507	$	184,183	$	3,837	$	1,125,405
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		1,008		—		1,008
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—		3,837		3,837
Transportation costs	6,930		83,261		43,221		—		133,412
Non-GAAP Segment coal sales revenues	$	415,948	$	431,246	$	139,954	$	—	$	987,148
Tons sold	34,289		3,685		3,602
Coal sales per ton sold	$	12.13	$	117.01	$	38.85

Six Months Ended June 30, 2018	Powder River Basin		Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	475,306	$	497,379	$	191,334	$	3,625	$	1,167,644
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		2,680		—		2,680
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—		3,625		3,625
Transportation costs	8,655		84,192		36,675		—		129,522
Non-GAAP Segment coal sales revenues	$	466,651	$	413,187	$	151,979	$	—	$	1,031,817
Tons sold	38,535		3,764		4,203
Coal sales per ton sold	$	12.11	$	109.78	$	36.16

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Segment cash cost per ton sold

Non-GAAP Segment cash cost per ton sold is calculated as segment cash cost of coal sales divided by segment tons sold. Segment cash cost of coal sales is adjusted for transportation costs, and may be adjusted for other items that, due to generally accepted accounting principles, are classified in “other income” on the statement of operations, but relate directly to the costs incurred to produce coal. Segment cash cost per ton sold is not a measure of financial performance in accordance with generally accepted accounting principles. We believe segment cash cost per ton sold better reflects our controllable costs and our operating results by including all costs incurred to produce coal. The adjustments made to arrive at these measures are significant in understanding and assessing our financial condition. Therefore, segment cash cost of coal sales should not be considered in isolation, nor as an alternative to cost of sales under generally accepted accounting principles.




Three Months Ended June 30, 2019	Powder River Basin			Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	195,948		$	159,419	$	88,749	$	6,972	$	451,088
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	(612		)	—		—		—		(612		)
Transportation costs	2,924			41,963		24,339		—		69,226
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		4,580		4,580
Other (operating overhead, certain actuarial, etc.)	—			—		—		2,392		2,392
Non-GAAP Segment cash cost of coal sales	193,636			117,456		64,410		—		375,502
Tons sold	17,149			1,892		1,916
Cash Cost Per Ton Sold	$	11.29		$	62.07	$	33.62

Three Months Ended June 30, 2018	Powder River Basin			Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	205,532		$	172,548	$	86,800	$	9,508	$	474,388
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	1,968			—		—		—		1,968
Transportation costs	3,176			49,308		23,281		—		75,765
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		6,731		6,731
Other (operating overhead, certain actuarial, etc.)	—			—		—		2,777		2,777
Non-GAAP Segment cash cost of coal sales	$	200,388		$	123,240	$	63,519	$	—	$	387,147
Tons sold	18,792			2,009		2,036
Cash Cost Per Ton Sold	$	10.66		$	61.33	$	31.19

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Six Months Ended June 30, 2019	Powder River Basin			Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	387,594		$	321,331	$	167,115	$	13,519	$	889,559
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	(1,251		)	—		—		—		(1,251		)
Transportation costs	6,930			83,261		43,221		—		133,412
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		8,819		8,819
Other (operating overhead, certain actuarial, etc.)	—			—		—		4,700		4,700
Non-GAAP Segment cash cost of coal sales	$	381,915		$	238,070	$	123,894	$	—	$	743,879
Tons sold	34,289			3,685		3,602
Cash Cost Per Ton Sold	$	11.14		$	64.60	$	34.39

Six Months Ended June 30, 2018	Powder River Basin			Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	424,059		$	327,310	$	161,988	$	15,811	$	929,168
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	2,407			—		—		—		2,407
Transportation costs	8,655			84,192		36,675		—		129,522
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		10,964		10,964
Other (operating overhead, certain actuarial, etc.)	—			—		—		4,847		4,847
Non-GAAP Segment cash cost of coal sales	$	412,997		$	243,118	$	125,313	$	—	$	781,428
Tons sold	38,535			3,764		4,203
Cash Cost Per Ton Sold	$	10.72		$	64.59	$	29.82

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Reconciliation of Segment Adjusted EBITDA to Net Income

The discussion in “Results of Operations” above includes references to our Adjusted EBITDA for each of our reportable segments. Adjusted EBITDA is defined as net income attributable to the Company before the effect of net interest expense, income taxes, depreciation, depletion and amortization, the amortization of sales contracts, the accretion on asset retirement obligations and nonoperating expenses. Adjusted EBITDA may also be adjusted for items that may not reflect the trend of future results by excluding transactions that are not indicative of our core operating performance. We use Adjusted EBITDA to measure the operating performance of our segments and allocate resources to our segments. Adjusted EBITDA is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDA are significant in understanding and assessing our financial condition. Therefore, Adjusted EBITDA should not be considered in isolation, nor as an alternative to net income, income from operations, cash flows from operations or as a measure of our profitability, liquidity or performance under generally accepted accounting principles. Investors should be aware that our presentation of Adjusted EBITDA may not be comparable to similarly titled measures used by other companies. The table below shows how we calculate Adjusted EBITDA.



	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In thousands)
Net income	$	62,840		$	43,306		$	135,581		$	103,291
Provision for (benefit from) income taxes	91			(3,366		)	161			(3,910		)
Interest expense, net	2,287			3,498			4,576			7,620
Depreciation, depletion and amortization	26,524			30,549			51,797			60,252
Accretion on asset retirement obligations	5,137			6,993			10,274			13,985
Amortization of sales contracts, net	11			3,248			76			6,299
Loss on sale of Lone Mountain Processing, LLC	4,304			—			4,304			—
Net loss resulting from early retirement of debt and debt restructuring	—			485			—			485
Non-service related pension and postretirement benefit costs	1,336			(68		)	3,102			1,235
Reorganization items, net	16			740			(71		)	1,041
Costs associated with proposed joint venture with Peabody Energy	3,018			—			3,018			—
Adjusted EBITDA	105,564			85,385			212,818			190,298
EBITDA from idled or otherwise disposed operations	1,473			2,832			567			5,411
Selling, general and administrative expenses	25,209			24,756			49,298			50,704
Other	(4,692		)	12,017			(16,893		)	5,489
Segment Adjusted EBITDA from coal operations	$	127,554		$	124,990		$	245,790		$	251,902

Other includes income from our equity investments, certain changes in fair value of heating oil and diesel fuel derivatives we use to manage our exposure to diesel fuel pricing, certain changes in the fair value of coal derivatives and coal trading activities, EBITDA provided by our land company, and certain miscellaneous revenue.

Liquidity and Capital Resources

Our primary sources of liquidity are proceeds from coal sales to customers and certain financing arrangements. Excluding significant investing activity, we intend to satisfy our working capital requirements and fund capital expenditures and debt-service obligations with cash generated from operations and cash on hand. Our focus is prudently managing costs, including capital expenditures, maintaining a strong balance sheet, and ensuring adequate liquidity.

On April 27, 2017, our Board of Directors authorized a share repurchase program for up to $300 million of our common stock, and has subsequently authorized additional amounts bringing the total authorization to $1.05 billion. During the quarter

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ended June 30, 2019, we repurchased 697,255 shares of our stock for approximately $63.4 million bringing total repurchases to 8,785,402 shares for approximately $725.5 million. The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on a number of factors, including business and market conditions, our future financial performance, and other capital priorities. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements. Our share repurchase program may be amended, suspended or discontinued at any time and does not commit us to repurchase shares of our common stock.

On April 27, 2017, our Board of Directors authorized a quarterly common stock cash dividend of $0.35 per share, which we increased to $0.40 per share on February 13, 2018. On February 14, 2019, we announced a further increase in the quarterly dividend to $0.45 per share. We paid a dividend of approximately $7.4 million on June 14, 2019 to stockholders of record at the close of business on May 31, 2019, bringing total dividends paid in 2019 to approximately $15.3 million, and total dividends paid since initiation to approximately $70.9 million.

Given the volatile nature of coal markets, we believe it is important to take a prudent approach to managing our balance sheet and liquidity. We plan to implement our dividend policy and share repurchase program in a manner that will result in maintaining liquidity levels between $400 million and $500 million, a significant portion of which will be cash. In the future, we will continue to evaluate our capital allocation initiatives in light of the current state of, and our outlook, for coal markets; the amount of our planned production that has been committed and priced; the capital needs of the business; and other strategic opportunities.

On March 7, 2017, we entered into a senior secured term loan credit agreement (the “Credit Agreement”) in an aggregate principal amount of $300 million (the “Term Loan Debt Facility”) with Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, and the other financial institutions from time to time party thereto. The Term Loan Debt Facility was issued at 99.50% of the face amount and will mature on March 7, 2024. The term loans provided under the Term Loan Debt Facility (the “Term Loans”) are subject to quarterly principal amortization payments in an amount equal to $750,000. For further information regarding the Term Loan Debt Facility see Note 10, “Debt and Financing Arrangements” to the Condensed Consolidated Financial Statements.

During 2018, we entered into the Second Amendment (the “Second Amendment”) to the Term Loan Debt Facility. The Second Amendment reduced the interest rate on the Term Loan Debt Facility to, at our option, either (i) LIBOR plus an applicable margin of 2.75%, subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 1.75%. For further information regarding this amendment see Note 10, “Debt and Financing Arrangements” to the Condensed Consolidated Financial Statements.

We have entered into a series of interest rate swaps to fix a portion of the LIBOR interest payments due under the term loan. As interest payments are made on the term loan, amounts in accumulated other comprehensive income will be reclassified into earnings through interest expense to reflect a net interest on the term loan equal to the effective yield of the fixed rate of the swap plus 2.75% which is the spread on the LIBOR term loan as amended. For further information regarding the interest rate swaps, including a table detailing fixed rates and amounts, see Note 10, “Debt and Financing Arrangements” to the Condensed Consolidated Financial Statements.

As of June 30, 2019, letters of credit totaling $15.7 million were outstanding under our Extended Securitization Facility with $86.5 million available for borrowings. Additionally, as of June 30, 2019, we had letters of credit totaling $35.6 million outstanding under our Inventory Facility with $14.4 million available for borrowings. For further information regarding the Extended Securitization Facility and the Inventory Facility see Note 10, “Debt and Financing Arrangements” to the Condensed Consolidated Financial Statements.

On June 30, 2019, we had total liquidity of approximately $508 million including $395 million in cash and equivalents, and short term investments in debt securities, with the remainder provided by availability under our credit facilities, and funds withdrawable from brokerage accounts.

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The following is a summary of cash provided by or used in each of the indicated types of activities during the six months ended June 30, 2019 and 2018:



	Six Months Ended June 30,
	2019			2018
	(In thousands)
Cash provided by (used in):
Operating activities	$	225,906		$	144,996
Investing activities	(89,693		)	(35,326		)
Financing activities	(168,721		)	(141,682		)

Cash Flow

Cash provided by operating activities in the six months ended June 30, 2019 increased from the six months ended June 30, 2018 mainly due to improved results from operations, a large favorable year over year change in working capital, particularly in receivables and payables, and receipt of an approximately $35 million income tax refund in the current year period, partially offset by receipt of an approximately $24 million income tax refund in the prior period.

Cash used in investing activities increased in the six months ended June 30, 2019 versus the six months ended June 30, 2018 primarily due to increased capital expenditures, including approximately $36 million on our Leer South mine development.

Cash used in financing activities in the six months ended June 30, 2019 increased from the six months ended June 30, 2018 primarily due to increased purchases of treasury stock of approximately $27 million.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

We manage our commodity price risk for our non-trading, thermal coal sales through the use of long-term coal supply agreements, and to a limited extent, through the use of derivative instruments. Sales commitments in the metallurgical coal market are typically not long term in nature, and we are therefore subject to fluctuations in market pricing.

Our sales commitments for 2019 were as follows as of July 24, 2019:



	2019
	Tons	$ per ton
Metallurgical	(in millions)
Committed, North America Priced Coking	1.1	$	126.45
Committed, North America Unpriced Coking	0.6	—
Committed, Seaborne Priced Coking	2.6	131.63
Committed, Seaborne Unpriced Coking	2.4

Committed, Priced Thermal	1.0	32.50
Committed, Unpriced Thermal	—

Powder River Basin
Committed, Priced	69.1	$	12.10
Committed, Unpriced	1.0

Other Thermal
Committed, Priced	7.1	$	39.53
Committed, Unpriced	0.7

We are also exposed to commodity price risk in our coal trading activities, which represents the potential future loss that could be caused by an adverse change in the market value of coal. Our coal trading portfolio included swap and put and call option contracts at June 30, 2019. The estimated future realization of the value of the trading portfolio is $0.6 million of losses during the remainder of 2019 and $0.5 million of losses during 2020.

We monitor and manage market price risk for our trading activities with a variety of tools, including Value at Risk (VaR), position limits, management alerts for mark to market monitoring and loss limits, scenario analysis, sensitivity analysis and review of daily changes in market dynamics. Management believes that presenting high, low, end of year and average VaR is the best available method to give investors insight into the level of commodity risk of our trading positions. Illiquid positions, such as long-dated trades that are not quoted by brokers or exchanges, are not included in VaR.

VaR is a statistical one-tail confidence interval and down side risk estimate that relies on recent history to estimate how the value of the portfolio of positions will change if markets behave in the same way as they have in the recent past. The level of confidence is 95%. The time across which these possible value changes are being estimated is through the end of the next business day. A closed-form delta-neutral method used throughout the finance and energy sectors is employed to calculate this VaR. VaR is back tested to verify its usefulness.

On average, portfolio value should not fall more than VaR on 95 out of 100 business days. Conversely, portfolio value declines of more than VaR should be expected, on average, 5 out of 100 business days. When more value than VaR is lost due to market price changes, VaR is not representative of how much value beyond VaR will be lost.

While presenting VaR will provide a similar framework for discussing risk across companies, VaR estimates from two independent sources are rarely calculated in the same way. Without a thorough understanding of how each VaR model was calculated, it would be difficult to compare two different VaR calculations from different sources.

During the six months ended June 30, 2019, VaR for our coal trading positions that are recorded at fair value through earnings ranged from under $0.1 million to $0.2 million. The linear mean of each daily VaR was $0.1 million. The final VaR at June 30, 2019 was near $0.0 million.

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We are exposed to fluctuations in the fair value of coal derivatives that we enter into to manage the price risk related to future coal sales, but for which we do not elect hedge accounting. Gains or losses on these derivative instruments would be largely offset in the pricing of the physical coal sale. During the six months ended June 30, 2019, VaR for our risk management positions that are recorded at fair value through earnings ranged from $0.7 million to $1.9 million. The linear mean of each daily VaR was $1.3 million. The final VaR at June 30, 2019 was $1.1 million.

We are exposed to price risk with respect to diesel fuel purchased for use in our operations. We anticipate purchasing approximately 40 to 47 million gallons of diesel fuel for use in our operations annually. To protect our cash flows from increases in the price of diesel fuel for our operations, we use forward physical diesel purchase contracts, purchased heating oil call options and NYMEX gulf coast diesel swaps and options. At June 30, 2019, we had protected the price on the majority of our expected diesel fuel purchases for the remainder of 2019 with approximately 10 million gallons of heating oil call options with an average strike price of $2.34 per gallon and 12 million gallons of NYMEX gulf coast diesel swaps at an average price of approximately $1.91 per gallon. Additionally, we have protected approximately 22% of our expected 2020 purchases using gulf coast diesel call options with an average strike price of $2.30 per gallon. At June 30, 2019, we had outstanding heating oil call options and NYMEX gulf coast swaps and options of approximately 32 million gallons for the purpose of managing the price risk associated with future diesel purchases. These positions are not designated as hedges for accounting purposes, and therefore, changes in the fair value are recorded immediately to earnings.

Item 4. Controls and Procedures.

We performed an evaluation under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures as of June 30, 2019. Based on that evaluation, our management, including our chief executive officer and chief financial officer, concluded that the disclosure controls and procedures were effective as of such date. There were no changes in our internal control over financial reporting during the fiscal quarter to which this report relates that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II

OTHER INFORMATION

Item 1. Legal Proceedings

We are involved in various claims and legal actions arising in the ordinary course of business, including employee injury claims. After conferring with counsel, it is the opinion of management that the ultimate resolution of these claims, to the extent not previously provided for, will not have a material adverse effect on our consolidated financial condition, results of operations or liquidity.

Item 1A. Risk Factors

The joint venture with Peabody may not be completed in a timely manner, or at all.

There can be no assurance that the joint venture with Peabody will be completed in a timely manner, or at all. Formation of the joint venture is subject to customary closing conditions, including the termination or expiration of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, the receipt of certain other required regulatory approvals and the absence of injunctions or other legal restraints preventing the formation of the joint venture. It is not certain that these closing conditions will be met or waived, that the necessary approvals will be obtained, or that we will be able to successfully enter into the joint venture.

We face risks and uncertainties due both to the pendency of the joint venture transaction as well as the potential failure to consummate the joint venture in a timely manner, or at all, including:


•	we may not realize any or all of the potential benefits of the joint venture, including expected synergies;


•	we will remain liable for significant transaction costs, including legal, financial advisory, accounting, and other costs relating to the joint venture, even if it is not consummated;


•	if the Implementation Agreement is terminated by us before we complete the joint venture, under certain circumstances, we may be required to pay a termination fee to Peabody of up to $40.0 million;


•	the pending joint venture transaction could have an adverse impact on our relationships with employees, customers and suppliers; and


•	the attention of our management and employees may be diverted from day-to-day operations.

The occurrence of any of these events individually or in combination could have a material adverse effect on our business, financial condition or results of operations.

There are risks associated with the conduct of joint ventures or joint operations.

To the extent we hold or acquire interests in any joint ventures or joint operations or enter into any joint ventures or joint operations in the future, including the pending joint venture with Peabody, the existence or occurrence of one or more of the following circumstances and events could have a material adverse impact on our profitability or the viability of our interests held through joint ventures, which could have a material adverse impact on our business, financial condition or results of operations:


•	inconsistent economic, political or business interests or goals between partners or disagreements with partners on strategy for the most efficient development or operation of mines;


•	inability to control certain strategic decisions made in respect of properties;


•	ability of partners to block actions that we believe to be in our or the joint venture’s best interests;


•	inability of partners to meet their financial and other obligations to the joint venture, joint operation or third parties; and


•	litigation between partners regarding management, funding or other decisions related to the joint venture or joint operation.

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To the extent that we are not the operator of a joint venture or joint operation properties, the success of such operations will be beyond our control. In many cases we will be bound by the decisions made by the operator in the operation of such property, and will rely on the operator to manage the property and to provide accurate information related to such property. We can provide no assurance that all decisions of operators of properties we do not control will achieve the expected results.

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

On July 26, 2018, the board of directors authorized an incremental $250 million increase to the share repurchase program bringing the total authorization to $750 million. On April 17, 2019, the board of directors authorized an additional $300 million to the share repurchase program, bringing the total authorization since the program’s launch to $1.05 billion. The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on a number of factors, including business and market conditions, our future financial performance, and other capital priorities. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements. The share repurchase program has no termination date, but may be amended, suspended or discontinued at any time and does not commit us to repurchase shares of our common stock. The actual number and value of the shares to be purchased will depend on the performance of our stock price and other market conditions.

The table below represents all share repurchases for the three months ended June 30, 2019:



Date	Total Number Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plan (in thousands) ⁽¹⁾
April 1 through April 30, 2019	311,019	$	91.63	311,019	$	359,369
May 1 through May 31, 2019	217,246	$	91.58	217,246	$	339,475
June 1 through June 30, 2019	168,990	$	88.76	168,990	$	324,475
Total	697,255	$	90.92	697,255

As of June 30, 2019, we had repurchased 8,785,402 shares at an average share price of $82.58 per share for an aggregate purchase price of approximately $726 million since inception of the stock repurchase program, and the remaining authorized amount for stock repurchases under this program is approximately $324 million.

Item 4. Mine Safety Disclosures.

The statement concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 to this Quarterly Report on Form 10-Q for the period ended June 30, 2019.

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Item 6. Exhibits.



2.1		Debtors’ Fourth Amended Joint Plan of Reorganization Under Chapter 11 of the Bankruptcy Code (incorporated by reference to Exhibit 2.1 of Arch Coal’s Current Report on Form 8-K filed on September 15, 2016).
2.2		Order Confirming Debtors’ Fourth Amended Joint Plan of Reorganization Under Chapter 11 of the Bankruptcy Code on September 13, 2016 (incorporated by reference to Exhibit 2.2 of Arch Coal’s Current Report on Form 8-K filed on September 15, 2016).
2.3		Implementation Agreement between Peabody Energy Corporation and Arch Coal, Inc. dated June 18, 2019 (incorporated by reference to Exhibit 2.1 of Arch Coal’s Current Report on Form 8-K/A filed on June 19, 2019).
3.1		Amended and Restated Certificate of Incorporation of Arch Coal, Inc. (incorporated by reference to Exhibit 3.1 of Arch Coal’s registration statement on Form 8-A filed on October 4, 2016).
3.2		Bylaws of Arch Coal, Inc. (incorporated by reference to Exhibit 3.2 of Arch Coal’s registration statement on Form 8-A filed on October 4, 2016).
4.1		Form of specimen Class A Common Stock certificate (incorporated by reference to Exhibit 4.1 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
4.2		Form of specimen Class B Common Stock certificate (incorporated by reference to Exhibit 4.2 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
4.3		Form of specimen Series A Warrant certificate (incorporated by reference to Exhibit A of Exhibit 10.5 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.1		Credit Agreement, dated as of March 7, 2017, among Arch Coal, Inc. as borrower, the lenders from time to time party thereto and Credit Suisse AG, Cayman Islands Branch, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on March 8, 2017).
10.2		First Amendment to Credit Agreement, dated as of September 25, 2017, among Arch Coal, Inc. as borrower, the lenders from time to time party thereto and Credit Suisse AG, Cayman Islands Branch, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on September 25, 2017).
10.3		Second Amendment to Credit Agreement, dated as of April 3, 2018, among Arch Coal, Inc. as borrower, the lenders from time to time party thereto and Credit Suisse AG, Cayman Islands Branch, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on April 3, 2018).
10.4		Credit Agreement, dated as of April 27, 2017, among Arch Coal, Inc. and certain of its subsidiaries, as borrowers, the lenders from time to time party thereto Regions Bank, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on May 2, 2017).
10.5		First Amendment to Credit Agreement dated November 19, 2018 by and among Arch Coal, Inc. and certain of its subsidiaries, as borrowers, the lenders from time to time party thereto Regions Bank, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.5 to Arch Coal’s Annual Report on Form 10-K for the year ended 2018).
10.6		Third Amended and Restated Receivables Purchase Agreement among Arch Receivable Company, LLC, as seller, Arch Coal Sales Company, Inc., as initial servicer, PNC Bank, National Association as administrator and issuer of letters of credit thereunder and the other parties party thereto, as securitization purchasers (incorporated by reference to Exhibit 10.2 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.7		First Amendment to Third Amended and Restated Receivables Purchase Agreement, dated as of April 27, 2017, among Arch Receivable Company, LLC, as seller, Arch Coal Sales Company, Inc., as servicer, PNC Bank, National Association as administrator and issuer of letters of credit thereunder and the other parties party thereto, as securitization purchasers (incorporated by reference to Exhibit 10.2 of Arch Coal’s Current Report on Form 8-K filed on May 2, 2017).
10.8		Second Amendment to Third Amended and Restated Receivables Purchase Agreement, dated as of August 27, 2018, among Arch Receivable Company, LLC, as seller, Arch Coal Sales Company, Inc., as servicer, PNC Bank, National Association as administrator and issuer of letters of credit thereunder and the other parties party thereto, as securitization purchasers (incorporated by reference to Exhibit 10.7 of Arch Coal’s Quarterly Report on Form 10-Q for the period ended September 30, 2018).
10.9		Third Amendment to Third Amended and Restated Receivables Purchase Agreement, dated as of May 1, 2019, among Arch Receivable Company, LLC, as seller, Arch Coal Sales Company, Inc., as servicer, PNC Bank, National Association as administrator and issuer of letters of credit thereunder and the other parties party thereto, as securitization purchasers (to be filed herewith).

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10.10		Second Amended and Restated Purchase and Sale Agreement among Arch Coal, Inc. and certain subsidiaries of Arch Coal, Inc., as originators (incorporated by reference to Exhibit 10.3 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.11		First Amendment to the Second Amended and Restated Purchase and Sale Agreement, dated as of December 21, 2016, among Arch Coal, Inc. and certain subsidiaries of Arch Coal, Inc., as originators (incorporated by reference to Exhibit 10.7 of Arch Coal’s Current Report on Form 8-K filed on October 31, 2017).
10.12		Second Amendment to the Second Amended and Restated Purchase and Sale Agreement, dated as of April 27, 2017, among the Arch Coal, Inc. and certain subsidiaries of the Arch Coal, Inc., as originators (incorporated by reference to Exhibit 10.3 of Arch Coal’s Current Report on Form 8-K filed on May 2, 2017).
10.13		Second Amended and Restated Sale and Contribution Agreement between Arch Coal, Inc., as the transferor, and Arch Receivable Company, LLC (incorporated by reference to Exhibit 10.4 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.14		First Amendment to the Second Amended and Restated Sale and Contribution Agreement, dated as of April 27, 2017, between Arch Coal, Inc., as the transferor, and Arch Receivable Company, LLC (incorporated by reference to Exhibit 10.4 of Arch Coal’s Current Report on Form 8-K filed on May 2, 2017).
10.15		Warrant Agreement, dated as of October 5, 2016, between Arch Coal, Inc. and American Stock Transfer & Trust Company, LLC, as Warrant Agent (incorporated by reference to Exhibit 10.5 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.16		Indemnification Agreement between Arch Coal and the directors and officers of Arch Coal and its subsidiaries (form) (incorporated by reference to Exhibit 10.6 of Arch Coal’s Current Report on Form 8-K filed on October 11, 2016).
10.17		Registration Rights Agreement between Arch Coal and Monarch Alternative Capital LP and certain other affiliated funds (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on November 21, 2016)
10.18		Coal Lease Agreement dated as of March 31, 1992, among Allegheny Land Company, as lessee, and UAC and Phoenix Coal Corporation, as lessors, and related guarantee (incorporated herein by reference to the Current Report on Form 8-K filed by Ashland Coal, Inc. on April 6, 1992).
10.19		Federal Coal Lease dated as of January 24, 1996 between the U.S. Department of the Interior and the Thunder Basin Coal Company (incorporated herein by reference to Exhibit 10.20 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 1998).
10.20		Federal Coal Lease Readjustment dated as of November 1, 1967 between the U.S. Department of the Interior and the Thunder Basin Coal Company (incorporated herein by reference to Exhibit 10.21 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 1998).
10.21		Federal Coal Lease effective as of May 1, 1995 between the U.S. Department of the Interior and Mountain Coal Company (incorporated herein by reference to Exhibit 10.22 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 1998).
10.22		Federal Coal Lease dated as of January 1, 1999 between the Department of the Interior and Ark Land Company (incorporated herein by reference to Exhibit 10.23 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 1998).
10.23		Federal Coal Lease effective as of March 1, 2005 by and between the United States of America and Ark Land LT, Inc. covering the tract of land known as “Little Thunder” in Campbell County, Wyoming (incorporated by reference to Exhibit 99.1 to the Current Report on Form 8-K filed by Arch Coal on February 10, 2005).
10.24		Modified Coal Lease (WYW71692) executed January 1, 2003 by and between the United States of America, through the Bureau of Land Management, as lessor, and Triton Coal Company, LLC, as lessee, covering a tract of land known as “North Rochelle” in Campbell County, Wyoming (incorporated by reference to Exhibit 10.24 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 2004).
10.25		Coal Lease (WYW127221) executed January 1, 1998 by and between the United States of America, through the Bureau of Land Management, as lessor, and Triton Coal Company, LLC, as lessee, covering a tract of land known as “North Roundup” in Campbell County, Wyoming (incorporated by reference to Exhibit 10.24 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 2004).
10.26*		Form of Employment Agreement for Executive Officers of Arch Coal, Inc. (incorporated herein by reference to Exhibit 10.4 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 2011).
10.27*		Arch Coal, Inc. Deferred Compensation Plan (incorporated herein by reference to Exhibit 10.26 to Arch Coal’s Annual Report on Form 10-K for the year ended December 31, 2014).
10.28		Arch Coal, Inc. Outside Directors’ Deferred Compensation Plan (incorporated herein by reference to Exhibit 10.4 of Arch Coal’s Current Report on Form 8-K filed on December 11, 2008).
10.29*		Arch Coal, Inc. Supplemental Retirement Plan (as amended on December 5, 2008) (incorporated herein by reference to Exhibit 10.2 to Arch Coal’s Current Report on Form 8-K filed on December 11, 2008).

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10.30*		Arch Coal, Inc. 2016 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 99.1 to Arch Coal’s Registration Statement on Form S-8 filed on November 1, 2016).
10.31*		Form of Restricted Stock Unit Contract (Time-Based Vesting) (incorporated herein by reference to Exhibit 10.1 to Arch Coal’s Current Report on Form 8-K filed on November 30, 2016).
10.32*		Form of Restricted Stock Unit Contract (Performance-Based Vesting) (incorporated herein by reference to Exhibit 10.2 to Arch Coal’s Current Report on Form 8-k filed on November 30, 2016).
10.33		Stock Repurchase Agreement dated September 13, 2017, among Arch Coal, Inc. and Monarch Alternative Solutions Master Fund Ltd, Monarch Capital Master Partners III LP, MCP Holdings Master LP, Monarch Debt Recovery Master Fund Ltd and P Monarch Recovery Ltd. (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on September 19, 2017).
10.34		Stock Repurchase Agreement dated December 8, 2017, among Arch Coal, Inc. and Monarch Alternative Solutions Master Fund Ltd, Monarch Capital Master Partners III LP, MCP Holdings Master LP, and Monarch Debt Recovery Master Fund Ltd (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on December 11, 2017).
10.35*		Form of Cash Retention Award Agreement for the Chief Executive Officer, Chief Operating Officer and Chief Financial Officer of the Company (incorporated by reference to Exhibit 10.37 to Arch Coal’s Annual Report on Form 10-K for the year ended 2018).
31.1		Rule 13a-14(a)/15d-14(a) Certification of John W. Eaves
31.2		Rule 13a-14(a)/15d-14(a) Certification of John T. Drexler.
32.1		Section 1350 Certification of John W. Eaves.
32.2		Section 1350 Certification of John T. Drexler.
95		Mine Safety Disclosure Exhibit.
101		Interactive Data File (Form 10-Q for the three and six months ended June 30, 2019 filed in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed.”

* Denotes a management contract or compensatory plan or arrangement.

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Signatures

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.



		Arch Coal, Inc.

		By:	/s/ John T. Drexler
			John T. Drexler
			Senior Vice President and Chief Financial Officer (On behalf of the registrant and as Principal Financial Officer)

			July 24, 2019