ARCH RESOURCES, INC. - Quarter Report: 2017 June (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

_________________________________________________________________

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2017

o 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

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 ý No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No o

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



Large accelerated filer o		Accelerated filer o

Non-accelerated filer ý		Smaller reporting company o
(Do not check if a smaller reporting company)
		Emerging growth company o

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 Securities Act. o

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

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 ý No o

At July 21, 2017, there were 24,310,578 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		26
Item 3. Quantitative and Qualitative Disclosure About Market Risk		39
Item 4. Controls and Procedures		40
Part II OTHER INFORMATION		40
Item 1. Legal Proceedings		40
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		40
Item 4. Mine Safety Disclosures		41
Item 6. Exhibits		42

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Part I

FINANCIAL INFORMATION

Item 1. Financial Statements.

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

	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
	(Unaudited)			(Unaudited)			(Unaudited)			(Unaudited)
Revenues	$	549,866		$	420,298		$	1,150,841		$	848,404
Costs, expenses and other operating
Cost of sales (exclusive of items shown separately below)	435,038			410,992			896,448			822,002
Depreciation, depletion and amortization	30,701			58,459			62,622			122,158
Accretion on asset retirement obligations	7,623			8,050			15,246			16,356
Amortization of sales contracts, net	14,352			1			29,042			(832		)
Change in fair value of coal derivatives and coal trading activities, net	863			1,158			1,717			2,368
Asset impairment and mine closure costs	—			43,701			—			129,221
Selling, general and administrative expenses	22,146			19,019			42,669			38,845
Other operating income, net	(3,549		)	(10,561		)	(5,859		)	(12,781		)
	507,174			530,819			1,041,885			1,117,337

Income (loss) from operations	42,692			(110,521		)	108,956			(268,933		)
Interest expense, net
Interest expense	(6,003		)	(45,273		)	(15,428		)	(89,724		)
Interest and investment income	842			933			1,369			2,071
	(5,161		)	(44,340		)	(14,059		)	(87,653		)

Income (loss) before nonoperating expenses	37,531			(154,861		)	94,897			(356,586		)

Nonoperating expenses
Net loss resulting from early retirement of debt and debt restructuring	(31		)	—			(2,061		)	(2,213		)
Reorganization items, net	(21		)	(21,271		)	(2,849		)	(25,146		)
	(52		)	(21,271		)	(4,910		)	(27,359		)

Income (loss) before income taxes	37,479			(176,132		)	89,987			(383,945		)
Provision for (benefit from) income taxes	319			(245		)	1,159			(1,356		)
Net income (loss)	$	37,160		$	(175,887	)	$	88,828		$	(382,589	)

Net income (loss) per common share
Basic earnings (loss) per common share	$	1.51		$	(8.26	)	$	3.58		$	(17.97	)
Diluted earnings (loss) per common share	$	1.48		$	(8.26	)	$	3.52		$	(17.97	)

Weighted average shares outstanding
Basic weighted average shares outstanding	24,659			21,293			24,834			21,293
Diluted weighted average shares outstanding	25,082			21,293			25,245			21,293

Dividends declared per common share	$	0.35		$	—		$	0.35		$	—

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)



	Successor		Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016			Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
	(Unaudited)		(Unaudited)			(Unaudited)			(Unaudited)
Net income (loss)	$	37,160	$	(175,887	)	$	88,828		$	(382,589	)

Derivative instruments
Comprehensive income (loss) before tax	257		(162		)	276			(386		)
Income tax benefit (provision)	—		—			—			81
	257		(162		)	276			(305		)
Pension, postretirement and other post-employment benefits
Comprehensive income (loss) before tax	3,154		(2,749		)	3,154			(4,087		)
Income tax benefit (provision)	—		—			—			481
	3,154		(2,749		)	3,154			(3,606		)
Available-for-sale securities
Comprehensive income (loss) before tax	—		504			(387		)	3,407
Income tax benefit (provision)	—		—			—			(1,043		)
	—		504			(387		)	2,364

Total other comprehensive income (loss)	3,411		(2,407		)	3,043			(1,547		)
Total comprehensive income (loss)	$	40,571	$	(178,294	)	$	91,871		$	(384,136	)

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,
	2017			2016
	(Unaudited)
Assets
Current assets
Cash and cash equivalents	$	333,548		$	305,372
Short term investments	159,822			88,072
Restricted cash	41,755			71,050
Trade accounts receivable	190,256			184,483
Other receivables	21,504			19,877
Inventories	137,056			113,462
Other current assets	61,474			96,306
Total current assets	945,415			878,622
Property, plant and equipment, net	1,007,570			1,053,603
Other assets
Equity investments	104,015			96,074
Other noncurrent assets	75,058			108,298
Total other assets	179,073			204,372
Total assets	$	2,132,058		$	2,136,597
Liabilities and Stockholders' Equity
Current Liabilities
Accounts payable	$	127,059		$	95,953
Accrued expenses and other current liabilities	169,533			205,240
Current maturities of debt	7,414			11,038
Total current liabilities	304,006			312,231
Long-term debt	315,639			351,841
Asset retirement obligations	342,680			337,227
Accrued pension benefits	32,092			38,884
Accrued postretirement benefits other than pension	101,407			101,445
Accrued workers’ compensation	186,128			184,568
Other noncurrent liabilities	65,048			63,824
Total liabilities	1,347,000			1,390,020

Stockholders' equity
Common stock, $0.01 par value, authorized 300,000 shares, issued 25,021 shares and 25,002 shares at June 30, 2017 and December 31, 2016, respectively	250			250
Paid-in capital	694,780			688,424
Retained earnings	113,574			33,449
Treasury stock, 711 shares at June 30, 2017, at cost	(51,043		)	—
Accumulated other comprehensive income	27,497			24,454
Total stockholders’ equity	785,058			746,577
Total liabilities and stockholders’ equity	$	2,132,058		$	2,136,597

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)



	Successor			Predecessor
	Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
	(Unaudited)			(Unaudited)
Operating activities
Net income (loss)	$	88,828		$	(382,589	)
Adjustments to reconcile to cash provided by operating activities:
Depreciation, depletion and amortization	62,622			122,158
Accretion on asset retirement obligations	15,246			16,356
Amortization of sales contracts, net	29,042			(832		)
Prepaid royalties expensed	2,288			1,770
Deferred income taxes	5,996			(418		)
Employee stock-based compensation expense	4,942			1,435
Gains on disposals and divestitures, net	(2,005		)	(6,269		)
Asset impairment and non-cash mine closure costs	—			119,194
Net loss resulting from early retirement of debt and debt restructuring	2,061			2,213
Non-cash bankruptcy reorganization items	—			(14,892		)
Amortization relating to financing activities	1,565			7,657
Changes in:
Receivables	(3,864		)	(7,776		)
Inventories	(23,594		)	21,152
Accounts payable, accrued expenses and other current liabilities	(89		)	84,160
Income taxes, net	(3,796		)	(937		)
Other	21,557			(22,634		)
Cash provided by (used in) operating activities	200,799			(60,252		)
Investing activities
Capital expenditures	(16,922		)	(74,137		)
Minimum royalty payments	(4,211		)	(217		)
Proceeds from (consideration paid for) disposals and divestitures	4,186			(3,303		)
Purchases of short term investments	(157,364		)	(98,750		)
Proceeds from sales of short term investments	85,035			94,589
Investments in and advances to affiliates, net	(8,934		)	(2,890		)
Withdrawals (deposits) of restricted cash	29,295			(4,695		)
Cash used in investing activities	(68,915		)	(89,403		)
Financing activities
Proceeds from issuance of term loan due 2024	298,500			—
Payments to extinguish term loan due 2021	(325,684		)	—
Payments on term loan due 2024	(750		)	—
Net payments on other debt	(5,207		)	(10,293		)
Debt financing costs	(8,900		)	(18,806		)
Net loss resulting from early retirement of debt and debt restructuring	(2,061		)	(2,213		)
Dividends paid	(8,563		)	—
Purchases of treasury stock	(51,043		)	—
Cash used in financing activities	(103,708		)	(31,312		)
Increase (decrease) in cash and cash equivalents	28,176			(180,967		)
Cash and cash equivalents, beginning of period	305,372			450,781
Cash and cash equivalents, end of period	$	333,548		$	269,814

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

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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 refer to both the Predecessor and Successor Company. 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, Kentucky, 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, 2017 are not necessarily indicative of results to be expected for the year ending December 31, 2017. 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, 2016 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

On January 11, 2016 (the “Petition Date”), Arch Coal and substantially all of its wholly owned domestic subsidiaries (the “Filing Subsidiaries” and, together with Arch Coal, the “Debtors” the Debtors, solely following the effective date of the Plan, the “Reorganized Debtors”) filed voluntary petitions for reorganization (collectively, the “Bankruptcy Petitions”) under Chapter 11 of Title 11 of the U.S. Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Eastern District of Missouri (the “Court”). The Debtors’ Chapter 11 Cases (collectively, the “Chapter 11 Cases”) were jointly administered under the caption In re Arch Coal, Inc., et al. Case No. 16-40120 (lead case). During the Chapter 11 Cases, each Debtor operated its business as a “debtor in possession” under the jurisdiction of the Court and in accordance with the applicable provisions of the Bankruptcy Code and the orders of the Court.

Upon emergence from bankruptcy on October 5, 2016, Arch Coal applied the provisions of fresh start accounting effective October 1, 2016 which resulted in Arch becoming a new entity for financial reporting purposes. Accordingly, the consolidated financial statements and accompanying footnotes on or after October 1, 2016 are not comparable to the consolidated financial statements prior to that date. References to “Successor” in the consolidated financial statements and footnotes are in reference to reporting dates on or after October 2, 2016; references to “Predecessor” in the consolidated financial statements and footnotes are in reference to reporting dates through October 1, 2016 which includes the impact of the Plan provisions and the application of fresh start accounting.

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2. Accounting Policies

Recently Adopted Accounting Guidance

In March 2016, the FASB issued Accounting Standards Update No. 2016-09, Compensation – Stock Compensation (Topic 718) ("ASU 2016-09"). ASU 2016-09 identifies areas for simplification involving several aspects of accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, an option to recognize gross stock compensation expense with actual forfeitures recognized as they occur, as well as certain classifications on the statement of cash flows. The Company adopted all provisions of this new accounting standard in the first quarter of 2017 and changed its forfeiture policy to recognize the impact of forfeitures when they occur from estimating expected forfeitures in determining stock-based compensation expense. There was no material impact to the Company's financial statements.

Recent Accounting Guidance Issued Not Yet Effective

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers.” ASU 2014-09 is a comprehensive revenue recognition standard that will supersede nearly all existing revenue recognition guidance under current U.S. GAAP and replace it with a principle based approach for determining revenue recognition. ASU 2014-09 will require that companies recognize revenue based on the value of transferred goods or services as they occur in the contract. The ASU also will require additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted only in annual reporting periods beginning after December 15, 2016, including interim periods therein. Entities will be able to transition to the standard either retrospectively or as a cumulative-effect adjustment as of the date of adoption. The Company’s primary source of revenue is from the sale of coal through both short-term and long-term contracts with utilities, industrial customers and steel producers whereby revenue is currently recognized when risk of loss has passed to the customer. Upon adoption of this new standard, the Company believes that the timing of revenue recognition related to its coal sales will remain consistent with its current practice. The Company is in the process of reviewing its portfolio of coal sales contracts and the various terms and clauses within each contract. Additionally, the Company is evaluating other revenue streams to determine the potential impact related to the adoption of the standard, as well as potential disclosures required by the standard. The Company will be adopting the standard under the modified retrospective approach.

In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715) Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. ASU 2017-07 changes the income statement presentation of defined benefit plan expense by requiring separation between operating expense (service cost component) and non-operating expense (all other components, including interest cost, amortization of prior service cost, curtailments and settlements, etc.). The operating expense component is reported with similar compensation costs while the non-operating components are reported in Nonoperating expense. In addition, only the service cost component is eligible for capitalization as part of an asset such as inventory or property, plant and equipment. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements. The ASU is effective for public companies for fiscal years beginning after December 15, 2017, and interim periods therein; early adoption is permitted.

3. 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, 2016	$	—	$	24,067		$	387		$	24,454
Unrealized gains (losses)	276		3,641			(55		)	3,862
Amounts reclassified from AOCI	—		(487		)	(332		)	(819		)
Balance at June 30, 2017	$	276	$	27,221		$	—		$	27,497

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The following amounts were reclassified out of AOCI:



	Successor		Predecessor		Successor		Predecessor			Line Item in the Condensed Consolidated Statement of Operations
Details About AOCI Components	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016		Six Months Ended June 30, 2017		Six Months Ended June 30, 2016
(In thousands)
Derivative instruments	$	—	$	96	$	—	$	321		Revenues
	—		—		—		(81		)	Provision for (benefit from) income taxes
	$	—	$	96	$	—	$	240		Net of tax

Pension, postretirement and other post-employment benefits
Amortization of prior service credits	$	—	$	2,672	$	—	$	5,344
Amortization of actuarial gains (losses), net	—		77		—		(1,257		)
Pension settlement	487		—		487		—
	487		2,749		487		4,087
	—		—		—		(481		)	Provision for (benefit from) income taxes
	$	487	$	2,749	$	487	$	3,606		Net of tax

Available-for-sale securities	$	—	$	—	$	332	$	(2,895	)	Interest and investment income
	—		—		—		1,038			Provision for (benefit from) income taxes
	$	—	$	—	$	332	$	(1,857	)	Net of tax

4. Reorganization items, net

In accordance with Accounting Codification Standard 852, “Reorganizations,” the statement of operations shall portray the results of operations of the reporting entity while it is in Chapter 11. Revenues, expenses (including professional fees), realized gains and losses, and provisions for losses resulting from reorganization and restructuring of the business shall be reported separately as reorganization items.

During the three months ended June 30, 2017 and 2016, the Company recorded a minimal charge in the current quarter and $21.3 million, respectively in “Reorganization items, net” primarily comprised of professional fee expenses. Net cash paid for “Reorganization items, net” totaled $0.9 million and $13.6 million during the three months ended June 30, 2017 and 2016, respectively.

During the six months ended June 30, 2017 and 2016, the Company recorded a charge of $2.8 million and $25.1 million, respectively, in “Reorganization items, net.” The 2017 amount is primarily comprised of professional fees and 2016 is comprised of $40.0 million in professional fees, partially offset by non-cash gains on rejected contracts of $14.9 million. Net cash paid for “Reorganization items, net” totaled $4.7 million and $15.1 million during the six months ended June 30, 2017 and 2016.

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5. Asset Impairment and Mine Closure Costs

During the second quarter of 2016, the Company recorded $43.7 million of “Asset impairment and mine closure costs” in the Condensed Consolidated Statements of Operations. The amount included the following: a $38.0 million impairment of the Company’s equity investment in a brownfield bulk commodity terminal on the Columbia River in Longview, Washington as the Company relinquished its ownership rights in exchange for future throughput rights; $3.6 million curtailment charge related to the Company’s pension, postretirement health and black lung actuarial liabilities due to headcount reductions in the first half of 2016; and $2.1 million of severance expense related to headcount reductions during the quarter.

During the first quarter of 2016, the Company recorded $85.5 million of “Asset impairment and mine closure costs” in the Condensed Consolidated Statements of Operations. The amount included the following: a $74.1 million impairment of coal reserves and surface land in Kentucky that are being leased to a mining company that idled its mining operations related to those reserves during the quarter; $5.1 million of severance expense related to headcount reductions at Company operations; $3.4 million related to an impairment charge on the portion of an advance royalty balance on a reserve base mined at the Company’s Mountain Laurel operation that was no longer deemed recoupable; and $2.9 million related to an other-than-temporary-impairment charge on an available-for-sale security.

6. Inventories

Inventories consist of the following:



	June 30,		December 31,
	2017		2016
	(In thousands)
Coal	$	60,887	$	37,268
Repair parts and supplies	76,169		76,194
	$	137,056	$	113,462

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $0.1 million at June 30, 2017 and $0.0 million at December 31, 2016.

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, along with the Company’s investments in marketable equity 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, 2017
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
U.S. treasury securities	$	57,382	$	32	$	(24	)	$	57,390	$	57,390	$	—
Corporate notes and bonds	102,497		10		(75		)	102,432		102,432		—
Total Investments	$	159,879	$	42	$	(99	)	$	159,822	$	159,822	$	—

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	December 31, 2016
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
Corporate notes and bonds	$	88,161	$	—	$	(89	)	$	88,072	$	88,072	$	—
Equity securities	1,749		388		—			2,137		—		2,137
Total Investments	$	89,910	$	388	$	(89	)	$	90,209	$	88,072	$	2,137

The aggregate fair value of investments with unrealized losses that were owned for less than a year was $92.0 million and $47.6 million at June 30, 2017 and December 31, 2016, respectively. The aggregate fair value of investments with unrealized losses that were owned for over a year was $20.7 million and $40.4 million at June 30, 2017 and December 31, 2016, respectively. The unrealized losses in the Company’s portfolio at June 30, 2017 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, 2017 have maturity dates ranging from the third quarter of 2017 through the third quarter of 2018. 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.

8. Sales Contracts

The sales contracts reflected in the consolidated balance sheets are as follows:



	June 30, 2017								December 31, 2016
	Assets			Liabilities			Net Total		Assets			Liabilities			Net Total
	(In thousands)								(In thousands)
Original fair value	$	97,196		$	31,742				$	97,196		$	31,742
Accumulated amortization	(59,408		)	(29,569		)			(25,625		)	(24,829		)
Total	$	37,788		$	2,173		$	35,615	$	71,571		$	6,913		$	64,658
Balance Sheet classification:
Other current	$	31,670		$	827				$	59,702		$	5,114
Other noncurrent	$	6,118		$	1,346				$	11,869		$	1,799

The Company anticipates amortization of sales contracts, based upon expected shipments in the next five years, to be an expense of approximately $54.4 million in 2017, $11.1 million in 2018, income of $0.6 million in 2019, and income of $0.1 million in 2020 and 2021.

9. Derivatives

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 45 million gallons of diesel fuel for use in its operations during 2017. 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 and purchased heating oil call options. At June 30, 2017, the Company had protected the price of approximately 70% of its expected diesel fuel purchases for the remainder of 2017 at an average strike price of $1.82 per gallon. Additionally, the Company has protected approximately 25% of its expected 2018 purchases with call options with an average strike price of $1.81 per gallon. At June 30, 2017, the Company had outstanding heating oil call options for approximately 27 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.

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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, 2017, the Company held derivatives for risk management purposes that are expected to settle in the following years:



(Tons in thousands)	2017	2018	Total
Coal sales	371	—	371
Coal purchases	363	—	363

The Company has also entered into a nominal 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. Additionally, the Company has also entered into a nominal quantity of foreign currency put options protecting for decreases in the Australian to United States dollar exchange rate, which could impact metallurgical 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 2017 and $0.8 million of losses during 2018.

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, 2017									December 31, 2016
Fair Value of Derivatives	Asset			Liability						Asset			Liability
(In thousands)	Derivative			Derivative						Derivative			Derivative
Derivatives Designated as Hedging Instruments
Coal	$	17		$	—					$	—		$	(15	)

Derivatives Not Designated as Hedging Instruments
Heating oil -- diesel purchases	661			—						4,646			—
Coal -- held for trading purposes	41,813			(43,157		)				68,948			(68,740		)
Coal -- risk management	67			(146		)				475			(580		)
Natural gas	103			(71		)				86			(13		)
Total	42,644			(43,374		)				74,155			(69,333		)
Total derivatives	42,661			(43,374		)				74,155			(69,348		)
Effect of counterparty netting	(41,947		)	41,947						(69,247		)	69,247
Net derivatives as classified in the balance sheets	$	714		$	(1,427	)	$	(713	)	$	4,908		$	(101	)	$	4,807

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		June 30, 2017			December 31, 2016
Net derivatives as reflected on the balance sheets (in thousands)
Heating oil and coal	Other current assets	$	714		$	4,908
Coal	Accrued expenses and other current liabilities	(1,427		)	(101		)
		$	(713	)	$	4,807

The Company had a current asset for the right to reclaim cash collateral of $4.6 million at June 30, 2017 and $2.8 million at December 31, 2016, 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.

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(Effective Portion)						Gains (Losses) Reclassified from Other Comprehensive Income into Income (Effective Portion)
		Successor			Predecessor			Successor		Predecessor
		2017			2016			2017		2016
Coal sales	⁽¹⁾	$	49		$	(73	)	$	—	$	157
Coal purchases	⁽²⁾	(34		)	6			—		(61		)
Totals		$	15		$	(67	)	$	—	$	96

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, 2017 and 2016.

Derivatives Not Designated as Hedging Instruments (in thousands)

Three Months Ended June 30,



		Gain (Loss) Recognized
		Successor			Predecessor
		2017			2016
Coal — unrealized	⁽³⁾	$	—		$	19
Coal — realized	⁽⁴⁾	$	—		$	(180	)
Natural gas — unrealized	⁽³⁾	$	(27	)	$	235
Heating oil — diesel purchases	⁽⁴⁾	$	(1,147	)	$	2,039
Foreign currency	⁽⁴⁾	$	—		$	34

____________________________________________________________

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

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Derivatives used in Cash Flow Hedging Relationships (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized in Other Comprehensive Income(Effective Portion)						Gains (Losses) Reclassified from Other Comprehensive Income into Income (Effective Portion)
		Successor			Predecessor			Successor		Predecessor
		2017			2016			2017		2016
Coal sales	⁽¹⁾	$	269		$	(60	)	$	—	$	1,526
Coal purchases	⁽²⁾	(234		)	(5		)	—		(1,205		)
Totals		$	35		$	(65	)	$	—	$	321

Derivatives Not Designated as Hedging Instruments (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized
		Successor			Predecessor
		2017			2016
Coal — unrealized	⁽³⁾	$	26		$	(1,096	)
Coal — realized	⁽⁴⁾	$	—		$	(343	)
Natural gas — unrealized	⁽³⁾	$	(496	)	$	(384	)
Heating oil — diesel purchases	⁽⁴⁾	$	(4,725	)	$	1,596
Foreign currency	⁽⁴⁾	$	—		$	(137	)

____________________________________________________________

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, 2017, 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 immaterial.

Related to its trading portfolio, the Company recognized net unrealized and realized losses of $0.8 million and $1.0 million during the three months ended June 30, 2017 and 2016, respectively; and net unrealized and realized losses of $1.5 million and $1.0 million during the six months ended June 30, 2017 and 2016, respectively. Gains and losses from trading activities are included in the caption “Change in fair value of coal derivatives and coal trading activities, net” in the accompanying Condensed Consolidated Statements of Operations, and are not included in the previous tables reflecting the effects of derivatives on measures of financial performance.

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10. Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist of the following:



	June 30,		December 31,
	2017		2016
	(In thousands)
Payroll and employee benefits	$	51,400	$	58,468
Taxes other than income taxes	78,132		92,733
Interest	130		8,032
Acquired sales contracts	827		5,114
Workers’ compensation	15,926		15,184
Asset retirement obligations	17,817		19,515
Other	5,301		6,194
	$	169,533	$	205,240

11. Debt and Financing Arrangements



	June 30,			December 31,
	2017			2016
	(In thousands)
Term loan due 2024 ($299.3 million face value)	$	297,808		$	—
Term loan due 2021 ($325.7 million face value)	—			325,684
Other	32,065			37,195
Debt issuance costs	(6,820		)	—
	323,053			362,879
Less: current maturities of debt	7,414			11,038
Long-term debt	$	315,639		$	351,841

Term Loan Facility

On March 7, 2017, the Company entered into a new senior secured term loan credit agreement in an aggregate principal amount of $300 million (the “New Term Loan Debt Facility) with Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent (in such capacities, the “Agent”), and the other financial institutions from time to time party thereto (collectively, the “Lenders”). The New Term Loan Debt Facility was issued at 99.50% of the face amount and will mature on March 7, 2024.

Borrowings under the New Term Loan Debt Facility bear interest at a per annum rate equal to, at the Company’s option, either (i) a London interbank offered rate plus an applicable margin of 4%, subject to a 1% LIBOR floor (the “LIBOR Rate”), or (ii) a base rate plus an applicable margin of 3%. The term loans provided under the New Term Loan Debt Facility (the “Term Loans”) are subject to quarterly principal amortization payments in an amount equal to $750,000.

The New 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 New 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 New Term Loan Debt Facility) and (ii) non-ordinary course asset sales or dispositions, subject to customary thresholds, exceptions and reinvestment rights.

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

The New 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 New Term Loan Debt Facility does not contain any financial maintenance covenant.

The New 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 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.

On the effective date of the New Term Loan Debt Facility, all outstanding obligations under the Company’s previously existing term loan credit agreement, dated as of October 5, 2016, among the Company, as borrower, the lender party thereto and Wilmington Trust, National Association, as administrative agent and collateral agent (the “Previous First Lien Debt Facility”), other than indemnification and other contingent obligations, were paid in cash in full and the related transaction documents were terminated (other than with respect to certain provisions that customarily survive termination); there was no gain or loss recognized on the extinguishment of the previously existing term loan credit agreement. All liens on property of the Company and the guarantors thereunder arising out of or related to the Previous First Lien Debt Facility were terminated.

Inventory-Based Revolving Credit Facility

On April 27, 2017, the Company and certain subsidiaries of Arch Coal entered into a new senior secured inventory-based revolving credit facility in an aggregate principal amount of $40 million (the “New Inventory Facility”) with Regions Bank (“Regions”) as administrative agent and collateral agent (in such capacities, the “Agent”), as lender and swingline lender (in such capacities, the “Lender”) and as letter of credit issuer. Availability under the New 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 New Inventory Facility), subject to reduction for reserves imposed by Regions.

The commitments under the New Inventory Facility will terminate on the date that is the earliest to occur of (i) the third anniversary of the Inventory Facility Closing Date, (ii) the date, if any, that is 364 days following the first day that Liquidity (defined in the New 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 (iii) 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 New Inventory Facility bear interest at a per annum rate equal to, at the option of Arch Coal, either at the base rate or the London interbank offered rate plus, in each case, a margin ranging from 2.25% to 2.50% (in the case of LIBOR loans) and 1.25% to 1.50% (in the case of base rate loans) determined using a Liquidity-based grid. Letters of credit under the New 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 New Inventory Facility (collectively with Arch Coal, the “Loan Parties”). The New Inventory Facility is secured by first priority security interests in the ABL Priority Collateral (defined in the New 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).

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Arch Coal has the right to prepay borrowings under the New Inventory Facility 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 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 New 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 New 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 New Inventory Facility also includes a requirement to maintain Liquidity equal to or exceeding $175 million at all times. As of June 30, 2017, letters of credit totaling $21.2 million were outstanding under the facility.

Accounts Receivable Securitization Facility

On April 27, 2017, 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 decreases the borrowing capacity from $200 million to $160 million and extends the maturity date to the date that is three years after the Securitization Facility Closing Date. 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 New 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, 2017, letters of credit totaling $130.4 million were outstanding under the facility which had a borrowing base of $88.7 million. As a result, cash collateral of $41.7 million has been placed in the facility and there is no availability for borrowings.

Interest Rate Swaps

During the second quarter of 2017, the Company 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 are 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 4% which is the spread on the 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 reclassified into earnings in the periods which the hedged forecasted transaction affects earnings.

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Below is a summary of the Company’s outstanding interest rate swap agreements designated as hedges as of June 30, 2017:



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

$	250.0	June 30, 2017	1.372	%	1-month LIBOR	June 29, 2018
$	250.0	June 29, 2018	1.662	%	1-month LIBOR	June 28, 2019
$	200.0	June 28, 2019	1.952	%	1-month LIBOR	June 30, 2020
$	100.0	June 30, 2020	2.182	%	1-month LIBOR	June 30, 2021

The fair value of the interest rate swaps at June 30, 2017 is an asset of $0.2 million which is recorded within Other noncurrent assets with the offset to accumulated other comprehensive income on the Company’s Condensed Consolidated Balance Sheet. The interest rate swaps are classified as level 2 within the fair value hierarchy.

Financing Costs

The Company paid financing costs of $8.9 million during the six months ended June 30, 2017; $7.2 million of which related to the issuance of the New Term Loan Debt facility discussed above. These issuance costs were capitalized during the first quarter and will be amortized using the effective interest method over the term of the facility. An additional $1.7 million is related to the inventory-based revolving credit facility and accounts receivable securitization facility. These issuance costs will be amortized on a straight-line basis over the term of the facility. During the six months ended June 30, 2016, the Company paid $18.8 million primarily related to the Superpriority Secured Debtor-in-Possession Credit Agreement related to the Company’s bankruptcy filing.

The Company incurred $2.1 million of legal and financial advisory fees associated with debt refinancing activities during the six months ended June 30, 2017; $1.0 million relates to fees associated with the extinguishment of the “Previous First Lien Debt Facility” while the remaining amount relates to financing fees incurred from initial efforts to replace the existing accounts receivable securitization facility. The Company also incurred $2.2 million in debt restructuring costs during the six months ended June 30, 2016 related to debt restructuring activities prior to the Company’s Chapter 11 filing.

Contractual Interest Expense During Bankruptcy

Upon the filing of bankruptcy, the Company discontinued recording interest expense on unsecured debt that was classified as a liability subject to compromise. Contractual interest expense during the three and six months ended June 30, 2016 was $100.8 million and $199.3 million.

12. Income Taxes

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



	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
(In thousands)
Income tax provision (benefit) at statutory rate	$	13,118		$	(61,645	)	$	31,496		$	(134,380	)
Percentage depletion allowance	(5,692		)	5,909			(12,731		)	(19,758		)
State taxes, net of effect of federal taxes	408			(2,571		)	891			(7,061		)
Change in valuation allowance	(8,316		)	58,665			(20,218		)	159,227
Other, net	801			(603		)	1,721			616
	$	319		$	(245	)	$	1,159		$	(1,356	)

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13. 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 available-for-sale equity securities, U.S. Treasury securities, and coal 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, interest rate swaps and commodity contracts (coal and heating oil) 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, 2017.

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, 2017
	Total		Level 1		Level 2		Level 3
	(In thousands)
Assets:
Investments in marketable securities	$	159,822	$	57,390	$	102,432	$	—
Derivatives	963		—		302		661
Total assets	$	160,785	$	57,390	$	102,734	$	661
Liabilities:
Derivatives	$	1,427	$	1,434	$	30	$	(37	)

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, 2017			Six Months Ended June 30, 2017
	(In thousands)
Balance, beginning of period	$	1,369		$	4,537
Realized and unrealized gains recognized in earnings, net	(1,332		)	(5,400		)
Purchases	1,158			2,553
Issuances	(317		)	(499		)
Settlements	(180		)	(493		)
Ending balance	$	698		$	698

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Net unrealized losses of $1.5 million and $1.3 million were recognized in the Condensed Consolidated Statement of Operations within Other operating income, net during the three and six months ended June 30, 2017 related to Level 3 financial instruments held on June 30, 2017.

Fair Value of Long-Term Debt

At June 30, 2017 and December 31, 2016, the fair value of the Company’s debt, including amounts classified as current, was $331.3 million and $362.9 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.

14. Earnings (loss) 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 (loss) per share by reconciling the numerators and denominators of the computations:



	Successor	Predecessor	Successor	Predecessor
	Three Months Ended June 30, 2017	Three Months Ended June 30, 2016	Six Months Ended June 30, 2017	Six Months Ended June 30, 2016
(In Thousands)
Weighted average shares outstanding:
Basic weighted average shares outstanding	24,659	21,293	24,834	21,293
Effect of dilutive securities	423	—	411	—

Diluted weighted average shares outstanding	25,082	21,293	25,245	21,293

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15. 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 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:



	Successor		Predecessor		Successor		Predecessor
	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016		Six Months Ended June 30, 2017		Six Months Ended June 30, 2016
(In thousands)
Self-insured occupational disease benefits:
Service cost	$	1,559	$	1,310	$	3,117	$	2,415
Interest cost	1,168		1,029		2,337		2,086
Net amortization	—		1,006		—		2,147
Curtailments	$	—	$	4,156	$	—	$	4,156
Total occupational disease	$	2,727	$	7,501	$	5,454	$	10,804
Traumatic injury claims and assessments	2,532		1,246		5,410		4,213
Total workers’ compensation expense	$	5,259	$	8,747	$	10,864	$	15,017

16. Employee Benefit Plans

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



	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
(In thousands)
Interest cost	$	2,991		$	3,197		$	5,982		$	6,535
Expected return on plan assets	(4,499		)	(4,444		)	(8,996		)	(8,982		)
Pension settlement	(487		)	454			(487		)	454
Amortization of other actuarial losses	—			924			—			1,681
Net benefit cost (credit)	$	(1,995	)	$	131		$	(3,501	)	$	(312	)

During the second quarter of 2017 the Company recorded a pension settlement related to its cash balance pension plan as the qualifying distributions from the plan exceeded the annual service and interest costs of the plan. Additionally, in accordance with accounting guidance, the Company revalued the cash balance pension liability which reduced the liability by approximately $3.6 million with the offset to accumulated other comprehensive income. The discount rate used for the revaluation was 3.59%.

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



	Successor		Predecessor			Successor		Predecessor
	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016			Six Months Ended June 30, 2017		Six Months Ended June 30, 2016
(In thousands)
Service cost	$	171	$	105		$	341	$	265
Interest cost	1,059		1,138			2,117		2,272
Curtailments	—		(970		)	—		(970		)
Amortization of prior service credits	—		(2,672		)	—		(5,345		)
Amortization of other actuarial losses (gains)	—		(566		)	—		(1,132		)
Net benefit cost (credit)	$	1,230	$	(2,965	)	$	2,458	$	(4,910	)

17. 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. As of June 30, 2017 and December 31, 2016, the Company had accrued $0.2 million and $2.2 million, respectively, for all legal matters, of which all amounts are classified as current. 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.

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18. 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 EBITDAR, 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 EBITDAR is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDAR are significant in understanding and assessing our financial condition. Therefore, Adjusted EBITDAR 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 EBITDAR 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 EBITDAR 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, Kentucky, and Virginia, and the Other Thermal segment containing the Company’s supplementary thermal operations in Colorado, Illinois, and West Virginia. Periods presented in this note have been recast for comparability.

Operating segment results for the Successor period, the three and six months ended June 30, 2017, and the Predecessor period, the three and six months ended June 30, 2016, are presented below. The Company measures its segments based on “adjusted earnings before interest, taxes, depreciation, depletion, amortization, accretion on asset retirements obligations, and reorganization items, net (Adjusted EBITDAR).” Adjusted EBITDAR does not reflect mine closure or impairment costs, since those are not reflected in the operating income reviewed by management. See Note 5, “Asset Impairment and Mine Closure Costs” for discussion of these costs. 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
Successor Periods	(in thousands)
Three Months Ended June 30, 2017
Revenues	$	230,579	$	227,649		$	91,639		$	(1	)	$	549,866
Adjusted EBITDAR	31,789		62,552			26,910			(25,883		)	95,368
Depreciation, depletion and amortization	8,574		18,385			3,285			457			30,701
Accretion on asset retirement obligation	5,040		528			540			1,515			7,623
Capital expenditures	822		6,825			1,899			1,426			10,972

Six Months Ended June 30, 2017
Revenues	$	504,007	$	453,232		$	193,545		$	57		$	1,150,841
Adjusted EBITDAR	79,794		130,862			54,152			(48,942		)	215,866
Depreciation, depletion and amortization	18,085		37,149			6,485			903			62,622
Accretion on asset retirement obligation	10,080		1,057			1,080			3,029			15,246
Capital expenditures	950		11,436			2,640			1,896			16,922

Predecessor Periods
Three Months Ended June 30, 2016
Revenues	$	207,735	$	147,499		$	60,032		$	5,032		$	420,298
Adjusted EBITDAR	21,578		(3,593		)	(408		)	(17,887		)	(310		)
Depreciation, depletion and amortization	30,145		17,330			9,907			1,077			58,459
Accretion on asset retirement obligation	5,647		588			663			1,152			8,050
Capital expenditures	489		6,726			949			60,047			68,211

Six Months Ended June 30, 2016
Revenues	$	430,857	$	284,083		$	116,164		$	17,300		$	848,404
Adjusted EBITDAR	34,306		2,759			2,743			(41,838		)	(2,030		)
Depreciation, depletion and amortization	62,905		36,675			19,798			2,780			122,158
Accretion on asset retirement obligation	11,293		1,177			1,325			2,561			16,356
Capital expenditures	499		10,330			2,895			60,413			74,137

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A reconciliation of adjusted EBITDAR to consolidated loss before income taxes follows:



	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30,			Three Months Ended June 30,			Six Months Ended June 30,			Six Months Ended June 30,
	2017			2016			2017			2016
(In thousands)
Adjusted EBITDAR	$	95,368		$	(310	)	$	215,866		$	(2,030	)
Depreciation, depletion and amortization	30,701			58,459			62,622			122,158
Accretion on asset retirement obligations	7,623			8,050			15,246			16,356
Amortization of sales contracts, net	14,352			1			29,042			(832		)
Asset impairment and mine closure costs	—			43,701			—			129,221
Interest expense, net	(5,161		)	(44,340		)	(14,059		)	(87,653		)
Net loss resulting from early retirement of debt and debt restructuring	(31		)	—			(2,061		)	(2,213		)
Reorganization items, net	(21		)	(21,271		)	(2,849		)	(25,146		)
Income (loss) before income taxes	$	37,479		$	(176,132	)	$	89,987		$	(383,945	)

19. Subsequent Events

On July 21, 2017, the Company entered into a definitive agreement to sell Lone Mountain Processing LLC, an operating mine complex within the Company’s metallurgical coal segment, and two idled mining companies, Cumberland River Coal LLC and Powell Mountain Energy LLC to Revelation Energy LLC. The purchase price is $8.3 million in cash, subject to customary adjustments for working capital and other items; the Company will retain certain workers’ compensation and employee-related obligations . The transaction is expected to close during the third quarter of 2017 and generate a net gain of approximately $15-20 million. The operations of Lone Mountain Processing LLC sold 0.7 million tons of coal in the first six months of 2017 while generating a pre-tax loss of $3.1 million.

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

Overview

Our results for the second quarter of 2017 benefited from relative strength in both the thermal and metallurgical markets. Although the domestic thermal coal market experienced normal seasonal weakness, it was supported by resilient natural gas pricing despite warmer than normal winter temperatures and a relatively cool start to the summer season. Natural gas production below year ago levels, along with increased natural gas export demand, kept natural gas pricing at levels where thermal coal, particularly Powder River Basin coal, remained economically competitive in many regions throughout the country for electrical generation during the period. Additionally, pricing in certain international thermal markets remained strong enough for some of our operations to be able to ship coal economically in these markets in the period.

Metallurgical coal markets remained strong in the second quarter of 2017, but the impact on our results from tropical cyclone Debbie was muted. On March 28th, tropical cyclone Debbie made landfall in Queensland, Australia, and significantly damaged the railroad infrastructure that supports the largest seaborne coking coal supply region in the world. This event is estimated to have impacted annual seaborne coking coal supply by between 10 and 15 million metric tons. Published pricing for prompt delivery of coking coal rose to historic levels in the aftermath of the cyclone; however, pricing has since returned to pre-cyclone levels. Customers largely avoided contracting business at the briefly elevated pricing seen in the immediate aftermath of Cyclone Debbie.

Filing Under Chapter 11 of the United States Bankruptcy Code

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Results of Operations - Successor

Three and Six Months Ended June 30, 2017

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 and six months ended June 30, 2017:



	Successor
	Three Months Ended June 30,		Six Months Ended June 30,
	2017		2017
	(In thousands)
Coal sales	$	549,866	$	1,150,841
Tons sold	22,521		48,199

On a consolidated basis, coal sales in the second quarter of 2017 by segment were approximately 42% Powder River Basin, 41% Metallurgical, and 17% Other, and coal sales in the first half of 2017 by segment were approximately 44% Powder River Basin, 39% Metallurgical, and 17% Other. Tons sold for the second quarter of 2017 by segment were approximately 80% Powder River Basin, 9% Metallurgical, and 10% Other, and tons sold for the first half of 2017 by segment were approximately 82% Powder River Basin, 9% Metallurgical, and 9% Other. See discussion in “Operational Performance” for further information about regional results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the three and six months ended June 30, 2017:



	Successor
	Three Months Ended June 30,			Six Months Ended June 30,
	2017			2017
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	435,038		$	896,448
Depreciation, depletion and amortization	30,701			62,622
Accretion on asset retirement obligations	7,623			15,246
Amortization of sales contracts, net	14,352			29,042
Change in fair value of coal derivatives and coal trading activities, net	863			1,717
Selling, general and administrative expenses	22,146			42,669
Other operating income, net	(3,549		)	(5,859		)
Total costs, expenses and other	$	507,174		$	1,041,885

Cost of sales. Our cost of sales for the second quarter of 2017, consisted primarily of labor related costs (approximately 29%), repairs and supplies (approximately 36%), operating taxes and royalties (approximately 21%), and transportation costs (approximately 13%), and for the first half of 2017, consisted primarily of labor related costs (approximately 27%), repairs and supplies (approximately 37%), operating taxes and royalties (approximately 21%), and transportation costs (approximately 14%). See discussion in “Operational Performance” for further information about regional results.

Depreciation, depletion and amortization. Our depreciation, depletion, and amortization costs for the second quarter of 2017 consist of depreciation of plant and equipment (approximately 63%), depletion of reserves (approximately 18%), and amortization of development costs (approximately 19%), and for the for the first half of 2017 consist of depreciation of plant and equipment (approximately 61%), depletion of reserves (approximately 18%), and amortization of development costs (approximately 21%). This reflects the application of fresh start accounting. For further information on fresh start accounting, please see Note 1 to the Consolidated Financial Statements, “Basis of Presentation.”

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Accretion on asset retirement obligation. Approximately 66% of the accretion on our asset retirement obligation in both the second quarter and the first half of 2017 is attributable to our large surface operations in the Powder River Basin.

Amortization of sales contracts, net. Our amortization of sales contracts, net is primarily related to the application of fresh start accounting to Powder River Basin supply contracts that had fixed prices that were above market upon our emergence from reorganization. For further information on fresh start accounting, please see Note 1 to the Consolidated Financial Statements, “Basis of Presentation.”

Selling, general and administrative expenses. Total selling, general and administrative expenses consisted primarily of compensation costs of $12.6 million in the second quarter and $26.5 million in the first half of 2017, and professional services and usage and maintenance agreements of $5.3 million in the second quarter and $10.2 million in the first half of 2017.

Other operating income, net. Other operating income, net consists primarily of miscellaneous revenues including outlease royalty income, transloading fees, and net gains on asset sales of $5.9 million in the second quarter and $11.5 million in the first half of 2017, and income from equity investments of $1.4 million in the second quarter and $3.4 million in the first half of 2017, partially offset by mark to market charges on heating oil derivatives of $1.1 million in the second quarter and $4.7 million in the first half of 2017, and miscellaneous expenses primarily related to our land company of $2.6 million in the second quarter and $4.3 million in the first half of 2017.

Nonoperating Expense. The following table summarizes our nonoperating expense during the three and six months ended June 30, 2017:



	Successor
	Three Months Ended June 30,			Six Months Ended June 30,
	2017			2017
	(In thousands)
Net loss resulting from early retirement of debt and debt restructuring	$	(31	)	$	(2,061	)
Reorganization items, net	(21		)	(2,849		)
Total nonoperating expense	$	(52	)	$	(4,910	)

Nonoperating expenses in the first half of 2017 are related to efforts to replace our securitization facility and expenses associated with our Chapter 11 reorganization. See further discussion in Note 4, “Reorganization Items, Net”, and Note 11, “Debt and Financing Arrangements”, to the condensed consolidated financial statements.

Provision for income taxes. The following table summarizes our provision from income taxes during the three and six months ended June 30, 2017:



	Successor
	Three Months Ended June 30,		Six Months Ended June 30,
	2017		2017
	(In thousands)
Provision for income taxes	$	319	$	1,159

See further discussion in Note 12, “Income Taxes”, to the condensed consolidated financial statements.

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Operational Performance - Successor

Three and Six Months Ended June 30, 2017

Our mining operations are evaluated based on Adjusted EBITDAR, 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 EBITDAR 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 reorganization items, net. Adjusted EBITDAR may also be adjusted for items that may not reflect the trend of future results. Adjusted EBITDAR is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDAR are significant in understanding and assessing our financial condition. Therefore, Adjusted EBITDAR 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 EBITDAR 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, 2017.



	Successor
	Three Months Ended June 30,		Six Months Ended June 30,
	2017		2017
Powder River Basin
Tons sold (in thousands)	18,092		39,418
Coal sales per ton sold	$	12.55	$	12.56
Cash cost per ton sold	$	10.82	$	10.55
Cash operating margin per ton sold	$	1.73	$	2.01
Adjusted EBITDAR (in thousands)	$	31,789	$	79,794
Metallurgical
Tons sold (in thousands)	2,104		4,164
Coal sales per ton sold	$	90.59	$	90.72
Cash cost per ton sold	$	60.95	$	59.33
Cash operating margin per ton sold	$	29.64	$	31.39
Adjusted EBITDAR (in thousands)	$	62,552	$	130,862
Other Thermal
Tons sold (in thousands)	2,325		4,617
Coal sales per ton sold	$	33.41	$	34.45
Cash cost per ton sold	$	22.06	$	22.93
Cash operating margin per ton sold	$	11.35	$	11.52
Adjusted EBITDAR (in thousands)	$	26,910	$	54,152

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 figures. 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 EBITDAR for the three and six months ended June 30, 2017, benefited from favorable natural gas pricing that maintained the competitiveness of Powder River Basin coal for electric generation versus the competing fuel. Despite unfavorably warm winter temperatures and a persistently mild spring, natural gas prices maintained favorable levels due to increased natural gas exports, both pipeline and liquefied natural gas, and stagnant to slightly declining natural gas production levels.

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Metallurgical —Adjusted EBITDAR for the three and six months ended June 30, 2017, benefited from continued strength in pricing for metallurgical coal. However, as discussed above, the impact on our results from tropical cyclone Debbie was muted. Cyclone Debbie significantly damaged the railroad infrastructure in Queensland, Australia and had an estimated impact on annual seaborne coking coal supply of between 10 and 15 million metric tons. As the extent of the damage became evident, published pricing for prompt delivery of coking coal rapidly rose to historic levels. However, pricing quickly returned to pre-cyclone levels, and customers largely avoided contracting business at the briefly elevated pricing seen in the immediate aftermath of Cyclone Debbie. Although we did not contract significant volumes at the briefly elevated prompt prices, pricing has remained at levels that provide significant margins to our low cost metallurgical operations. Our metallurgical segment sold 1.5 million tons of coking coal, 0.2 million tons of PCI Coal, and 0.3 million tons of associated thermal coal in the second quarter of 2017 and 3.1 million tons of coking coal, 0.3 million tons of PCI Coal, and 0.8 million tons of associated thermal coal in the first half of 2017. Longwall operations accounted for approximately 53% of our shipment volume in the second quarter and 55% of our shipment volume in the first half of 2017.

Other Thermal— Adjusted EBITDAR for the three and six months ended June 30, 2017, benefited from the favorable natural gas pricing discussed in the Powder River Basin segment discussion above, and international thermal prices that supported certain export sales. These benefits were primarily recognized at our low cost West Elk longwall operation where domestic and export opportunities were economic.

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Results of Operations - Predecessor

Three and Six Months Ended June 30, 2016

Coal Sales. The following table summarizes information about our coal sales during the three and six months ended June 30, 2016:



	Predecessor
	Three Months Ended June 30,		Six Months Ended June 30,
	2016		2016
	(In thousands)
Coal sales	$	420,298	$	848,404
Tons sold	19,454		39,603

On a consolidated basis, coal sales in the second quarter of 2016 by segment were approximately 50% Powder River Basin, 35% Metallurgical, and 14% Other, and coal sales in the first half of 2016 by segment were approximately 51% Powder River Basin, 33% Metallurgical, and 14% Other. Tons sold for the second quarter of 2016 by segment were approximately 80% Powder River Basin, 12% Metallurgical, and 7% Other, and tons sold for the first half of 2016 by segment were approximately 81% Powder River Basin, 11% Metallurgical, and 7% Other. See discussion in “Operational Performance” for further information about regional results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the three and six months ended June 30, 2016:



	Predecessor
	Three Months Ended June 30,			Six Months Ended June 30,
	2016			2016
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	410,992		$	822,002
Depreciation, depletion and amortization	58,459			122,158
Accretion on asset retirement obligations	8,050			16,356
Amortization of sales contracts, net	1			(832		)
Change in fair value of coal derivatives and coal trading activities, net	1,158			2,368
Asset impairment and mine closure costs	43,701			129,221
Selling, general and administrative expenses	19,019			38,845
Other operating income, net	(10,561		)	(12,781		)
Total costs, expenses and other	$	530,819		$	1,117,337

Cost of sales. Our cost of sales for the second quarter of 2016, consisted primarily of labor related costs (approximately 28%), repairs and supplies (approximately 33%), operating taxes and royalties (approximately 18%), and transportation costs (approximately 10%), and for the first half of 2016, consisted primarily of labor related costs (approximately 29%), repairs and supplies (approximately 35%), operating taxes and royalties (approximately 19%), and transportation costs (approximately 10%). See discussion in “Operational Performance” for further information about regional results.

Depreciation, depletion and amortization. Our depreciation, depletion, and amortization costs for the second quarter of 2016 consist of depreciation of plant and equipment (approximately 59%), depletion of reserves (approximately 32%), and amortization of development costs (approximately 9%), and for the for the first half of 2016 consist of depreciation of plant and equipment (approximately 58%), depletion of reserves (approximately 33%), and amortization of development costs (approximately 9%).

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Accretion on asset retirement obligation. In the second quarter and first half of 2016 respectively, approximately 70% and 69% of the accretion on our asset retirement obligation is attributable to our large surface operations in the Powder River Basin.

Asset impairment and mine closure costs. During the second quarter of 2016 we sold our 38% equity interest in Millennium Bulk Terminal in a non-cash transaction. As a result of this sale we determined our remaining investment in Millennium Bulk Terminal was impaired. Earlier in the first half of 2016 we received notification of intent to idle operations by a third party to whom we leased certain Appalachian reserves. As a result of the idling and weakness in the thermal coal market we determined the value of these reserves was impaired. See further discussion in Note 5, “Asset Impairment and Mine Closure”.

Selling, general and administrative expenses. Total selling, general and administrative expenses consisted primarily of compensation costs of $11.9 million in the second quarter and $24.7 million in the first half of 2016, and professional services and usage and maintenance agreements of $4.2 million in the second quarter and $8.2 million in the first half of 2016.

Other operating income, net. Other operating income, net consists primarily of miscellaneous revenues including outlease royalty income and net gains on asset sales of $9.1 million in the second quarter and $14.3 million in the first half of 2016, income from equity investments of $1.6 million in the second quarter and $3.4 million in the first half of 2016, and benefit from mark to market charges on heating oil derivatives of $2.0 million in the second quarter and $1.6 million in the first half of 2016. These were partially offset by miscellaneous expenses primarily related to our land company of $2.0 million in the second quarter and $4.1 million in the first half of 2016, and by liquidated damages on logistics contracts of $1.6 million in the first half of 2016.

Nonoperating Expense. The following table summarizes our nonoperating expense during the three and six months ended June 30, 2016:



	Predecessor
	Three Months Ended June 30,			Six Months Ended June 30,
	2016			2016
	(In thousands)
Net loss resulting from early retirement of debt and debt restructuring	$	—		$	(2,213	)
Reorganization items, net	(21,271		)	(25,146		)
Total nonoperating expense	$	(21,271	)	$	(27,359	)

Nonoperating expenses in the second quarter and first half of 2016 are related to our proposed debt restructuring activities and costs associated with our Chapter 11 reorganization. See further discussion in Note 4, “Reorganization Items, Net”.

Provision for (benefit from) income taxes. The following table summarizes our provision from income taxes during the three and six months ended June 30, 2016:



	Predecessor
	Three Months Ended June 30,			Six Months Ended June 30,
	2016			2016
	(In thousands)
Provision for (benefit from) income taxes	$	(245	)	$	(1,356	)

See further discussion in Note 12, “Income Taxes”, to the condensed consolidated financial statements.

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Operational Performance - Predecessor

Three and Six Months Ended June 30, 2016

The following table shows results by operating segment for the three and six months ended June 30, 2016.



	Predecessor
	Three Months Ended June 30,			Six Months Ended June 30,
	2016			2016
Powder River Basin
Tons sold (in thousands)	15,639			32,144
Coal sales per ton sold	$	13.08		$	13.16
Cash cost per ton sold	$	11.72		$	12.10
Cash operating margin per ton sold	$	1.36		$	1.06
Adjusted EBITDAR (in thousands)	$	21,578		$	34,306
Metallurgical
Tons sold (in thousands)	2,307			4,472
Coal sales per ton sold	$	52.94		$	52.05
Cash cost per ton sold	$	54.52		$	51.45
Cash operating margin per ton sold	$	(1.58	)	$	0.60
Adjusted EBITDAR (in thousands)	$	(3,593	)	$	2,759
Other Thermal
Tons sold (in thousands)	1,436			2,712
Coal sales per ton sold	$	35.76		$	37.66
Cash cost per ton sold	$	36.39		$	36.83
Cash operating margin per ton sold	$	(0.63	)	$	0.83
Adjusted EBITDAR (in thousands)	$	(408	)	$	2,743

Powder River Basin — Adjusted EBITDAR for the three and six months ended June 30, 2016, was negatively impacted by historically low natural gas pricing that made Powder River Basin coal economically uncompetitive for electric generation versus the competing fuel for many of our customers. Unfavorably warm 2015-2016 winter season temperatures and increased natural gas production levels from shale resources kept the price of the competing fuel at unsustainably low levels through most of the first half of 2016.

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Metallurgical —Adjusted EBITDAR for the three and six months ended June 30, 2016, was negatively impacted by multi-year lows in pricing for metallurgical coal. Persistent oversupply from significant investments early in the decade, particularly in Australia, long term anemic economic growth in OECD nations, and slowing economic growth in China led to a multi-year cyclical downturn in metallurgical coal pricing. Our metallurgical segment sold 1.6 million tons of coking coal, 0.2 million tons of PCI Coal, and 0.5 million tons of associated thermal coal in the second quarter of 2016 and 3.1 million tons of coking coal, 0.2 million tons of PCI Coal, and 1.1 million tons of associated thermal coal in the first half of 2016. Longwall operations accounted for approximately 58% of our shipment volume in the second quarter and 64% of our shipment volume in the first half of 2016.

Other Thermal— Adjusted EBITDAR for the three and six months ended June 30, 2016, was negatively impacted by the low natural gas pricing discussed in the Powder River Basin segment discussion above. Furthermore, international thermal prices did not support thermal export sales at any of our operations during these periods.

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Reconciliation of Non-GAAP measures

Segment coal sales per ton sold

Segment coal sales per ton sold are calculated as the segment's coal sales revenues divided by segment tons sold. The segments' sales per tons sold are adjusted for transportation costs, and may be adjusted for other items that, due to accounting rules, are classified in "other operating (income) expense, net" on the statement of operations, but relate to price protection on the sale of coal. Segment sales per ton sold is not a measure of financial performance in accordance with generally accepted accounting principles. We believe segment sales per ton sold 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.



	Successor		Predecessor		Successor		Predecessor
	Three Months Ended June 30,		Three Months Ended June 30,		Six Months Ended June 30,		Six Months Ended June 30,
	2017		2016		2017		2016

(In thousands)
Reported segment coal sales revenues	$	495,400	$	377,991	$	1,031,965	$	957,879
Coal risk management derivative settlements classified in “other (income) expense, net”	—		185		—		330
Coal sales revenues from idled or otherwise disposed operations not included in segments	—		4,283		50		14,856
Transportation costs	54,466		37,840		118,825		75,338
Revenues in the condensed consolidated statements of operations	$	549,866	$	420,298	$	1,150,841	$	848,404

Segment cost per ton sold

Segment costs per ton sold are calculated as the segment’s cost of tons sold divided by segment tons sold. The segments’ cost of tons sold are adjusted for transportation costs, and may be adjusted for other items that, due to accounting rules, are classified in “other (income) expense, net” on the statement of operations, but relate directly to the costs incurred to produce coal. Segment cost of tons sold is not a measure of financial performance in accordance with generally accepted accounting principles. We believe segment cost of tons 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 cost of tons sold should not be considered in isolation, nor as an alternative to cost of sales under generally accepted accounting principles.



	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30,			Three Months Ended June 30,			Six Months Ended June 30,			Six Months Ended June 30,
	2017			2016			2017			2016

(In thousands)
Reported segment cash cost of tons sold	$	375,214		$	361,246		$	768,948		$	718,875
Diesel fuel risk management derivative settlements classified in “other (income) expense, net”	(891		)	(1,209		)	(1,495		)	(2,543		)
Transportation costs	54,466			37,840			118,825			75,338
Cash cost of coal sold from idled or otherwise disposed operations not included in segments	5,233			13,178			8,681			29,495
Other (operating overhead, certain actuarials, etc.)	1,016			(63		)	1,489			837
Cost of sales in the condensed consolidated statements of operations	$	435,038		$	410,992		$	896,448		$	822,002

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Reconciliation of Segment Adjusted EBITDAR to Net Income

The discussion in “Results of Operations” above includes references to our Adjusted EBITDAR for each of our reportable segments. Adjusted EBITDAR 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 reorganization items, net. Adjusted EBITDAR may also be adjusted for items that may not reflect the trend of future results. We use Adjusted EBITDAR to measure the operating performance of our segments and allocate resources to our segments. Adjusted EBITDAR is not a measure of financial performance in accordance with generally accepted accounting principles, and items excluded from Adjusted EBITDAR are significant in understanding and assessing our financial condition. Therefore, Adjusted EBITDAR 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 EBITDAR may not be comparable to similarly titled measures used by other companies. The table below shows how we calculate Adjusted EBITDAR.



	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30,			Three Months Ended June 30,			Six Months Ended June 30,			Six Months Ended June 30,
	2017			2016			2017			2016
(In thousands)
Reported Segment Adjusted EBITDAR	$	121,250		$	17,578		$	264,808		$	39,808
EBITDA from idled or otherwise disposed operations	(4,698		)	(2,213		)	(6,934		)	(6,840		)
Selling, general, and administrative expenses	(22,146		)	(19,020		)	(42,669		)	(38,845		)
Other	962			3,345			661			3,847
Adjusted EBITDAR	95,368			(310		)	215,866			(2,030		)
Provision for (benefit from) income taxes	(319		)	245			(1,159		)	1,356
Interest expense, net	(5,161		)	(44,340		)	(14,059		)	(87,653		)
Depreciation, depletion and amortization	(30,701		)	(58,459		)	(62,622		)	(122,158		)
Accretion on asset retirement obligations	(7,623		)	(8,050		)	(15,246		)	(16,356		)
Amortization of sales contracts, net	(14,352		)	(1		)	(29,042		)	832
Asset impairment and mine closure costs	—			(43,701		)	—			(129,221		)
Net loss resulting from early retirement of debt and debt restructuring	(31		)	—			(2,061		)	(2,213		)
Reorganization items, net	(21		)	(21,271		)	(2,849		)	(25,146		)
Net income (loss)	$	37,160		$	(175,887	)	$	88,828		$	(382,589	)

Other includes primarily income from our equity investments, certain actuarial adjustments, and certain changes in the fair value of coal derivatives and coal trading activities.

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 insuring adequate liquidity.

On April 27, 2017, our Board of Directors authorized a new share repurchase program for up to $300 million of our common stock, and a new quarterly common stock cash dividend of $0.35 per share. During the second quarter of 2017, we repurchased 710,701 shares of our stock for approximately $51 million. Also during the second quarter of 2017, we paid a quarterly cash dividend of $0.35 per share, totaling approximately $8.6 million. The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on market conditions. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements.

Given the volatile nature of coal markets, we believe it is important to take a prudent approach to managing our balance sheet and liquidity. Our dividend policy and share repurchase program will be implemented in a manner that will result

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in maintaining cash levels similar to those we have seen over the past three quarters. 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 new senior secured term loan credit agreement in an aggregate principal amount of $300 million (the “New Term Loan Debt Facility”) with Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent (in such capacities, the “Agent”), and the other financial institutions from time to time party thereto (collectively, the “Lenders”). The New Term Loan Debt Facility was issued at 99.50% of the face amount and will mature on March 7, 2024. Proceeds from The New Term Loan Debt Facility were used to repay all outstanding obligations under our previously existing term loan credit agreement, dated as of October 5, 2016.

Borrowings under the New Term Loan Debt Facility bear interest at a per annum rate equal to, at our option, either (i) a London interbank offered rate plus an applicable margin of 4%, subject to a 1% LIBOR floor (the “LIBOR Rate”), or (ii) a base rate plus an applicable margin of 3%. Interest payments will be payable in cash. The term loans provided under the New 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 Previous First Lien Debt Facility and the New Term Loan Debt Facility see Note 11 to the Condensed Consolidated Financial Statements “Debt and Financing Arrangements”.

During the second quarter of 2017, we 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 are recorded on our 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 4% which is the spread on the 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 reclassified into earnings in the periods which the hedged forecasted transaction affects earnings. For further information regarding the interest rate swaps see Note 11 to the Condensed Consolidated Financial Statements “Debt and Financing Arrangements”.

On April 27, 2017, we entered into a new senior secured inventory-based revolving credit facility in an aggregate principal amount of $40 million (the “New Inventory Facility”) with Regions Bank (“Regions”) as administrative agent and collateral agent (in such capacities, the “Agent”), as lender and swingline lender (in such capacities, the “Lender”) and as letter of credit issuer. Availability under the New 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 our Eligible Cash (defined in the New Inventory Facility), subject to reduction for reserves imposed by Regions.

Revolving loan borrowings under the New Inventory Facility bear interest at a per annum rate equal to, at our option, either at the base rate or the London interbank offered rate plus, in each case, a margin ranging from 2.25% to 2.50% (in the case of LIBOR loans) and 1.25% to 1.50% (in the case of base rate loans) determined using a Liquidity-based grid. Letters of credit under the New Inventory Facility are subject to a fee in an amount equal to the applicable margin for LIBOR loans, plus customary fronting and issuance fees. For further information regarding the New Inventory Facility see Note 11 to the Condensed Consolidated Financial Statements “Debt and Financing Arrangements”.

On April 27, 2017, we extended and amended our existing trade accounts receivable securitization facility which supports the issuance of letters of credit and requests for cash advances. The amendment to the Extended Securitization Facility decreases the borrowing capacity from $200 million to $160 million and extends the maturity date to three years after the Securitization Facility Closing Date. Pursuant to the Extended Securitization Facility, we also agreed to a revised schedule of fees payable to the administrator and the providers of the Extended Securitization Facility. For further information regarding the Extended Securitization Facility see Note 11 to the Condensed Consolidated Financial Statements “Debt and Financing Arrangements”.

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On June 30, 2017 we had total liquidity of approximately $513 million including unrestricted cash and equivalents, short term investments in debt securities, availability under our credit facilities, and funds withdrawable from brokerage accounts.

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, 2017 and 2016:



	Successor			Predecessor
	Six Months Ended June 30,			Six Months Ended June 30,
	2017			2016
(In thousands)
Cash provided by (used in):
Operating activities	$	200,799		$	(60,252	)
Investing activities	(68,915		)	(89,403		)
Financing activities	(103,708		)	(31,312		)

Cash Flow - Successor

Cash provided by operating activities in the six months ended June 30, 2017 resulted from improved market conditions for most of our products and solid operating cost performance across all of our segments discussed in the Operational Performance section above. In addition, low cash interest expense contributed to the cash provided by operating activities.

Cash used in investing activities in the six months ended June 30, 2017 resulted from the net purchase of short term investments, additional investment in our equity holding of Dominion Terminal Associates of approximately $7 million, and capital expenditures of approximately $17 million, partially offset by an approximately $29 million reduction in restricted cash.

Cash used in financing activities in the six months ended June 30, 2017 resulted primarily from our purchase of approximately $51 million of treasury stock, payment of our $0.35 per share cash dividend, and the repayment of the Previous First Lien Debt Facility with proceeds from the New Term Loan Debt Facility. Additionally, financing costs associated with the New Term Loan Debt Facility added to cash used in financing activities.

Cash Flow - Predecessor

Cash used in operating activities in the six months ended June 30, 2016, resulted from difficult market conditions for all of our products as discussed in the Operational Performance section above. In addition, significant cash interest expense and cash restructuring costs contributed to cash used in operating activities.

Cash used in investing activities in the six months ended June 30, 2016 resulted from additions to restricted cash of approximately $5 million as collateral requirements under the Predecessor securitization facility increased over the period and capital expenditures of approximately $74 million including approximately $60 million for the final Lease by Application (LBA) bonus bid payment for a Powder River Basin reserve tract.

Cash used in financing activities in the six months ended June 30, 2016 resulted from financing costs associated with the previous DIP facility and securitization facility, insurance premium financing payments, and expenses related to pre-filing debt restructuring costs.

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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 2017 and 2018 were as follows as of July 27, 2017 (the table below includes sales commitments related to our Lone Mountain Processing, LLC operation which we have entered into a definitive agreement to sell; see Note 19 to the Consolidated Financial Statements, “Subsequent Events,” for additional information):



	2017			2018
	Tons	$ per ton		Tons	$ per ton
Metallurgical	(in millions)			(in millions)
Committed, Priced Coking	5.0	$	97.21	0.1	$	97.37
Committed, Unpriced Coking	1.4			2.0

Committed, Priced PCI	0.7	$	67.05	—	$	—
Committed, Unpriced PCI	—			—

Committed, Priced Thermal	1.4	$	41.19	0.4	$	30.33
Committed, Unpriced Thermal	—			—

Powder River Basin
Committed, Priced	76.4	$	12.47	36.5	$	12.20
Committed, Unpriced	1.8			3.0

Other Thermal
Committed, Priced	8.4	$	34.61	2.9	$	37.94
Committed, Unpriced	—			—

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, 2017. The estimated future realization of the value of the trading portfolio is $0.6 million of losses during the remainder of 2017 and 0.8 million of losses during the remainder of 2018.

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.

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During the six months ended June 30, 2017, VaR for our coal trading positions that are recorded at fair value through earnings ranged from under $0.1 million to $0.5 million. The linear mean of each daily VaR was $0.2 million. The final VaR at June 30, 2017 was $0.3 million.

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, 2017, VaR for our risk management positions that are recorded at fair value through earnings ranged from $0.0 million to $0.2 million. The linear mean of each daily VaR was $0.1 million. The final VaR at June 30, 2017 was $0.1 million.

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, 2017. 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.

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 2. Unregistered Sales of Equity Securities and Use of Proceeds

On April 27, 2017, the board of directors of Arch Coal authorized a new share repurchase program for up to $300 million of its common stock, effective April 27, 2017. The timing of any purchases, and the ultimate number of shares to be purchased, will depend on market conditions. 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 may be amended, suspended or discontinued at any time and does not commit the Company to repurchase shares of its common stock. The actual number and value of the shares to be purchased will depend on the performance of the our stock price and other market conditions.

During the second quarter of 2017, we repurchased 710,701 shares of our stock for approximately $51 million and placed them in treasury.

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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, 2017.

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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).
3.1		Amended and Restated Certificate of Incorporation of Arch Coal, Inc. 10.19 (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		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).
10.3		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).
10.4		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).
10.5		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).
10.6		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).
10.7		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).
10.8		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).
10.9		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).
10.10		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).
10.11		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)
10.12		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).

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10.13		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).
10.14		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).
10.15		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).
10.16		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).
10.17		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).
10.18		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).
10.19		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).
10.20		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).
10.21		Arch Coal, Inc. Incentive Compensation Plan For Executive Officers (incorporated herein by reference to Appendix B to the proxy statement on Schedule 14A filed by Arch Coal on March 22, 2010).
10.22		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).
10.23		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).
10.24		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).
10.25		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).
10.26		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).
10.27		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).
10.28		Form of Performance Unit Contract (incorporated herein by reference to Exhibit 10.2 to Arch Coal’s Quarterly Report on Form 10-Q for the period ended March 31, 2013).
10.29		Form of Director Indemnity Agreement (incorporated herein by reference to Exhibit 10.40 to Arch Coal’s Annual Report on Form 10-K for the period ended December 31, 2010).
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, 2017 filed in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed.”

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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 27, 2017