ARCH 10-Q Quarterly Report June 30, 2018

ARCH RESOURCES, INC.

10-Ks and 10-Qs

10-Q	Quarter ended June 30, 2022
10-Q	Quarter ended March 31, 2022
10-K	Fiscal year ended Dec. 31, 2021
10-Q	Quarter ended Sept. 30, 2021
10-Q	Quarter ended June 30, 2021
10-Q	Quarter ended March 31, 2021
10-K	Fiscal year ended Dec. 31, 2020
10-Q	Quarter ended Sept. 30, 2020
10-Q	Quarter ended June 30, 2020
10-Q	Quarter ended March 31, 2020
10-K	Fiscal year ended Dec. 31, 2019
10-Q	Quarter ended Sept. 30, 2019
10-Q	Quarter ended June 30, 2019
10-Q	Quarter ended March 31, 2019
10-K	Fiscal year ended Dec. 31, 2018
10-Q	Quarter ended Sept. 30, 2018
10-Q	Quarter ended June 30, 2018
10-Q	Quarter ended March 31, 2018
10-K	Fiscal year ended Dec. 31, 2017
10-Q	Quarter ended Sept. 30, 2017
10-Q	Quarter ended June 30, 2017
10-Q	Quarter ended March 31, 2017
10-K	Fiscal year ended Dec. 31, 2016
10-Q	Quarter ended Sept. 30, 2016
10-Q	Quarter ended June 30, 2016
10-Q	Quarter ended March 31, 2016
10-K	Fiscal year ended Dec. 31, 2015
10-Q	Quarter ended Sept. 30, 2015
10-Q	Quarter ended June 30, 2015
10-Q	Quarter ended March 31, 2015
10-K	Fiscal year ended Dec. 31, 2014
10-Q	Quarter ended Sept. 30, 2014
10-Q	Quarter ended June 30, 2014
10-Q	Quarter ended March 31, 2014
10-K	Fiscal year ended Dec. 31, 2013
10-Q	Quarter ended Sept. 30, 2013
10-Q	Quarter ended June 30, 2013
10-Q	Quarter ended March 31, 2013
10-K	Fiscal year ended Dec. 31, 2012
10-Q	Quarter ended Sept. 30, 2012
10-Q	Quarter ended June 30, 2012
10-Q	Quarter ended March 31, 2012
10-K	Fiscal year ended Dec. 31, 2011
10-Q	Quarter ended Sept. 30, 2011
10-Q	Quarter ended June 30, 2011
10-Q	Quarter ended March 31, 2011
10-K	Fiscal year ended Dec. 31, 2010
10-Q	Quarter ended Sept. 30, 2010
10-Q	Quarter ended June 30, 2010
10-Q	Quarter ended March 31, 2010
10-K	Fiscal year ended Dec. 31, 2009

PROXIES

DEF 14A	Filed on May 7, 2024
DEF 14A	Filed on March 27, 2024
DEF 14A	Filed on March 31, 2023
DEF 14A	Filed on May 13, 2022
DEF 14A	Filed on March 30, 2022
DEF 14A	Filed on March 15, 2021
DEF 14A	Filed on March 16, 2020
DEF 14A	Filed on March 18, 2019
DEF 14A	Filed on March 19, 2018
DEF 14A	Filed on March 22, 2017
DEF 14A	Filed on March 20, 2015
DEF 14A	Filed on March 14, 2014
DEF 14A	Filed on March 12, 2013
DEF 14A	Filed on March 16, 2012
DEF 14A	Filed on March 18, 2011
DEF 14A	Filed on March 22, 2010

10-Q 1 aci-20180630x10q.htm 10-Q Document

Table of Contents

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, 2018

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, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):



Large accelerated filer ý		Accelerated filer o

Non-accelerated filer o		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 27, 2018 , there were 19,587,748 shares of the registrant’s common stock outstanding.

Table of Contents

TABLE OF CONTENTS



		Page
Part 1 FINANCIAL INFORMATION		3
Item 1. Financial Statements		3
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations		29
Item 3. Quantitative and Qualitative Disclosure About Market Risk		43
Item 4. Controls and Procedures		44
Part II OTHER INFORMATION		45
Item 1. Legal Proceedings		45
Item 1A. Risk Factors		45
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		46
Item 4. Mine Safety Disclosures		46
Item 6. Exhibits		47
Signatures		50

Table of Contents

Part I

FINANCIAL INFORMATION

Item 1. Financial Statements.

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(Unaudited)						(Unaudited)
Revenues	$	592,349		$	549,866		$	1,167,644		$	1,150,841
Costs, expenses and other operating
Cost of sales (exclusive of items shown separately below)	474,388			434,465			929,168			894,915
Depreciation, depletion and amortization	30,549			30,701			60,252			62,622
Accretion on asset retirement obligations	6,993			7,623			13,985			15,246
Amortization of sales contracts, net	3,248			14,352			6,299			29,042
Change in fair value of coal derivatives and coal trading activities, net	15,138			863			11,724			1,717
Selling, general and administrative expenses	24,756			22,456			50,704			43,218
Other operating income, net	(7,318		)	(3,518		)	(14,250		)	(5,828		)
	547,754			506,942			1,057,882			1,040,932

Income from operations	44,595			42,924			109,762			109,909
Interest expense, net
Interest expense	(5,050		)	(6,003		)	(10,445		)	(15,428		)
Interest and investment income	1,552			842			2,825			1,369
	(3,498		)	(5,161		)	(7,620		)	(14,059		)

Income before nonoperating expenses	41,097			37,763			102,142			95,850

Nonoperating expenses
Non-service related pension and postretirement benefit (costs) credits	68			(232		)	(1,235		)	(953		)
Net loss resulting from early retirement of debt and debt restructuring	(485		)	(31		)	(485		)	(2,061		)
Reorganization items, net	(740		)	(21		)	(1,041		)	(2,849		)
	(1,157		)	(284		)	(2,761		)	(5,863		)

Income before income taxes	39,940			37,479			99,381			89,987
Provision for (benefit from) income taxes	(3,366		)	319			(3,910		)	1,159
Net income	$	43,306		$	37,160		$	103,291		$	88,828

Net income per common share
Basic earnings per common share	$	2.15		$	1.51		$	5.03		$	3.58
Diluted earnings per common share	$	2.06		$	1.48		$	4.81		$	3.52

Weighted average shares outstanding
Basic weighted average shares outstanding	20,156			24,659			20,529			24,834
Diluted weighted average shares outstanding	21,036			25,082			21,456			25,245

Dividends declared per common share	$	0.40		$	0.35		$	0.80		$	0.35

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

Table of Contents

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (Loss)

(in thousands)



	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018			2017
	(Unaudited)					(Unaudited)
Net income	$	43,306		$	37,160	$	103,291		$	88,828

Derivative instruments
Comprehensive income (loss) before tax	(12,293		)	257		(5,736		)	276
Income tax benefit (provision)	—			—		—			—
	(12,293		)	257		(5,736		)	276
Pension, postretirement and other post-employment benefits
Comprehensive income (loss) before tax	3,653			3,154		3,653			3,154
Income tax benefit (provision)	—			—		—			—
	3,653			3,154		3,653			3,154
Available-for-sale securities
Comprehensive income (loss) before tax	177			—		(481		)	(387		)
Income tax benefit (provision)	—			—		—			—
	177			—		(481		)	(387		)

Total other comprehensive income (loss)	(8,463		)	3,411		(2,564		)	3,043
Total comprehensive income	$	34,843		$	40,571	$	100,727		$	91,871

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

Table of Contents

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(in thousands, except per share data)



	June 30,			December 31,
	2018			2017
	(Unaudited)
Assets
Current assets
Cash and cash equivalents	$	241,590		$	273,387
Short term investments	160,894			155,846
Trade accounts receivable	198,362			172,604
Other receivables	12,612			29,771
Inventories	157,205			128,960
Other current assets	86,642			70,426
Total current assets	857,305			830,994
Property, plant and equipment, net	925,559			955,948
Other assets
Equity investments	104,189			106,107
Other noncurrent assets	62,360			86,583
Total other assets	166,549			192,690
Total assets	$	1,949,413		$	1,979,632
Liabilities and Stockholders' Equity
Current Liabilities
Accounts payable	$	131,027		$	134,137
Accrued expenses and other current liabilities	194,730			184,161
Current maturities of debt	12,533			15,783
Total current liabilities	338,290			334,081
Long-term debt	305,157			310,134
Asset retirement obligations	316,341			308,855
Accrued pension benefits	7,481			14,036
Accrued postretirement benefits other than pension	106,934			102,369
Accrued workers’ compensation	185,068			184,835
Other noncurrent liabilities	49,194			59,457
Total liabilities	1,308,465			1,313,767

Stockholders' equity
Common stock, $0.01 par value, authorized 300,000 shares, issued 25,047 shares at June 30, 2018 and December 31, 2017, respectively	250			250
Paid-in capital	708,127			700,125
Retained earnings	333,753			247,232
Treasury stock, 5,344 shares and 3,977 shares at June 30, 2018 and December 31, 2017, respectively, at cost	(418,985		)	(302,109		)
Accumulated other comprehensive income	17,803			20,367
Total stockholders’ equity	640,948			665,865
Total liabilities and stockholders’ equity	$	1,949,413		$	1,979,632

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

Table of Contents

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(in thousands)



	Six Months Ended June 30,
	2018			2017
	(Unaudited)
Operating activities
Net income	$	103,291		$	88,828
Adjustments to reconcile to cash provided by operating activities:
Depreciation, depletion and amortization	60,252			62,622
Accretion on asset retirement obligations	13,985			15,246
Amortization of sales contracts, net	6,299			29,042
Prepaid royalties expensed	—			2,288
Deferred income taxes	8,730			5,996
Employee stock-based compensation expense	7,992			4,942
Gains on disposals and divestitures, net	131			(2,005		)
Net loss resulting from early retirement of debt and debt restructuring	485			2,061
Amortization relating to financing activities	2,170			1,565
Changes in:
Receivables	(20,212		)	(3,864		)
Inventories	(28,245		)	(23,594		)
Accounts payable, accrued expenses and other current liabilities	(11,879		)	(89		)
Income taxes, net	11,560			(3,796		)
Other	(9,563		)	21,557
Cash provided by operating activities	144,996			200,799
Investing activities
Capital expenditures	(30,049		)	(16,922		)
Minimum royalty payments	(124		)	(4,211		)
Proceeds from disposals and divestitures	56			4,186
Purchases of short term investments	(110,359		)	(157,364		)
Proceeds from sales of short term investments	105,150			85,035
Investments in and advances to affiliates, net	—			(8,934		)
Cash used in investing activities	(35,326		)	(98,210		)
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	(1,500		)	(750		)
Net payments on other debt	(7,307		)	(5,207		)
Debt financing costs	(529		)	(8,900		)
Net loss resulting from early retirement of debt and debt restructuring	(50		)	(2,061		)
Dividends paid	(16,333		)	(8,563		)
Purchases of treasury stock	(115,973		)	(51,043		)
Other	10			—
Cash used in financing activities	(141,682		)	(103,708		)
Decrease in cash and cash equivalents, including restricted cash	(32,012		)	(1,119		)
Cash and cash equivalents, including restricted cash, beginning of period	273,602			376,422
Cash and cash equivalents, including restricted cash, end of period	$	241,590		$	375,303

Cash and cash equivalents, including restricted cash, end of period
Cash and cash equivalents	$	241,590		$	333,548
Restricted cash	—			41,755
	$	241,590		$	375,303

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

Table of Contents

Arch Coal, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(unaudited)

1. Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include the accounts of Arch Coal, Inc. ("Arch Coal") and its subsidiaries (the “Company”). Unless the context indicates otherwise, the terms “Arch” and the “Company” are used interchangeably in this Quarterly Report on Form 10-Q. The Company’s primary business is the production of thermal and metallurgical coal from surface and underground mines located throughout the United States, for sale to utility, industrial and steel producers both in the United States and around the world. The Company currently operates mining complexes in West Virginia, Illinois, Wyoming and Colorado. All subsidiaries are wholly-owned. Intercompany transactions and accounts have been eliminated in consolidation.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States for interim financial reporting and U.S. Securities and Exchange Commission regulations. In the opinion of management, all adjustments, consisting of normal, recurring accruals considered necessary for a fair presentation, have been included. Results of operations for the three and six months ended June 30, 2018 are not necessarily indicative of results to be expected for the year ending December 31, 2018 . 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, 2017 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

2. Accounting Policies

Recently Adopted Accounting Guidance

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers.” ASU 2014-09 is a comprehensive revenue recognition standard that has superseded nearly all existing revenue recognition guidance under current U.S. GAAP and replaced it with a principle based approach for determining revenue recognition. ASU 2014-09 requires that companies recognize revenue based on the value of transferred goods or services as they occur in the contract. The ASU also requires 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. 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. During the fourth quarter of 2017, the Company finalized its assessment related to the new standard by analyzing certain contracts representative of the majority of the Company’s coal sales and determined that the timing of revenue recognition related to the Company’s coal sales will remain consistent between the new standard and the previous standard. The Company also reviewed other sources of revenue, and concluded the current basis of accounting for these items is in accordance with the new standard. The Company adopted ASU 2014-09 effective January 1, 2018 using the modified retrospective method, and there was no cumulative adjustment to retained earnings. The Company also reviewed the disclosure requirements under the new standard and has compiled information needed for the expanded disclosures which are included within Note 18 , “ Revenue Recognition ” in the Condensed Consolidated Financial Statements.

In August 2016, the FASB issued ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments.” The amendment requires the classification of certain cash receipts and cash payments in the statement of cash flows to reduce diversity in practice. The new guidance is effective for fiscal years beginning after December 15, 2017 and the interim periods therein, with early adoption permitted. The amendments in the classification should be applied retrospectively to all periods presented, unless deemed impracticable, in which case, the prospective application is permitted. The Company adopted ASU 2016-15 effective January 1, 2018 with no impact on the Company’s financial statements.

Table of Contents

In November 2016, FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash.” The ASU applies to all entities that have restricted cash or restricted cash equivalents and are required to present a statement of cash flows. The ASU requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. As a result, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning of period and end of period total amounts shown on the statement of cash flows. The ASU is effective for public business entities for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. The ASU should be adopted using a retrospective transition method to each period presented. The Company adopted ASU 2016-18 effective January 1, 2018 and applied the ASU retrospectively to the periods presented in the Company's Condensed Consolidated Statements of Cash Flow. As a result, net cash used in investing activities for the six months ended June 30, 2017 was adjusted to exclude the change in restricted cash as follows:



(in thousands)	Six Months Ended June 30, 2017
Cash used in investing activities previously reported	$	(68,915	)
Less: Withdrawals of restricted cash	29,295

Cash used in investing activities	$	(98,210	)

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 ASU is effective for public companies for fiscal years beginning after December 15, 2017, and interim periods therein. The ASU should be adopted using a retrospective transition method to each period presented. The Company adopted ASU 2017-07 effective January 1, 2018 and applied the ASU retrospectively to the periods presented in the Company's Condensed Consolidated Income Statements. The retrospective application resulted in a $0.6 million and $1.5 million reduction in cost of coal sales and a $0.3 million and $0.5 million increase in selling, general and administrative costs with the corresponding offset to Nonoperating expense for the three and six months ended June 30, 2017 .

Recent Accounting Guidance Issued Not Yet Effective

In February 2016, the FASB issued ASU 2016-02, “Leases” which, for operating leases, requires a lessee to recognize a right-of-use asset and a lease liability, initially measured at the present value of the lease payments, in its balance sheet. The standard also requires a lessee to recognize a single lease cost, calculated so that the cost of the lease is allocated over the term of the lease, on a generally straight line basis. The ASU is effective for public companies for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years; early adoption is permitted. The Company has both operating and capital leases. We expect the adoption of this standard to result in the recognition of right-of-use assets and lease liabilities not currently recorded on the Company’s financial statements. The Company is currently in the process of accumulating all contractual lease arrangements in order to determine the impact on its financial statements.

In August 2017, the FASB issued ASU 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” The new guidance provides targeted improvements to the accounting for hedging activities to better align an entity’s risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedging results. ASU 2017-12 is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years; early adoption is permitted. The Company anticipates early adopting the standard in the third quarter of 2018, although we do not expect a significant impact to the Company’s financial results.

In February 2018, the FASB issued ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220) Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” ASU 2018-02 provides an option to reclassify stranded tax effects within accumulated other comprehensive income to retained earnings due to the change in the U.S. federal tax rate in the Tax Cuts and Jobs Act of 2017. The ASU is effective for public companies for fiscal years beginning after

Table of Contents

December 15, 2018, and interim periods therein with early adoption permitted. The Company is currently in the process of analyzing the standard, but does not expect a significant impact to the Company’s financial statements.

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, 2017	$	647		$	19,720		$	—		$	20,367
Unrealized gains (losses)	(5,248		)	5,024			(465		)	(689		)
Amounts reclassified from AOCI	(488		)	(1,371		)	(16		)	(1,875		)
Balance at June 30, 2018	$	(5,089	)	$	23,373		$	(481	)	$	17,803

The following amounts were reclassified out of AOCI:



	Three Months Ended June 30,				Six Months Ended June 30,
Details About AOCI Components	2018		2017		2018		2017		Line Item in the Condensed Consolidated Statement of Operations
(In thousands)
Coal hedges	$	—	$	—	$	—	$	—	Revenues
Interest rate hedges	348		—		488		—		Interest expense
	—		—		—		—		Provision for (benefit from) income taxes
	$	348	$	—	$	488	$	—	Net of tax

Pension, postretirement and other post-employment benefits
Pension settlement	1,371		487		1,371		487		Non-service related pension and postretirement benefit (costs) credits
	1,371		487		1,371		487
	—		—		—		—		Provision for (benefit from) income taxes
	$	1,371	$	487	$	1,371	$	487	Net of tax

Available-for-sale securities	$	16	$	—	$	16	$	332	Interest and investment income
	—		—		—		—		Provision for (benefit from) income taxes
	$	16	$	—	$	16	$	332	Net of tax

Table of Contents

4. Reorganization items, net

In accordance with Accounting Codification Standard 852, “Reorganizations,” the income statement 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, 2018 and 2017 , the Company recorded $0.7 million and near $0.0 million , respectively in “Reorganization items, net” primarily comprised of professional fee expenses. Net cash paid for “Reorganization items, net” totaled $0.3 million and $0.9 million during the three months ended June 30, 2018 and 2017 , respectively.

During the six months ended June 30, 2018 and 2017 , the Company recorded $1.0 million and $2.8 million , respectively in “Reorganization items, net” primarily comprised of professional fee expenses. Net cash paid for “Reorganization items, net” totaled $0.6 million and $4.7 million during the six months ended June 30, 2018 and 2017 , respectively.

5. Inventories

Inventories consist of the following:



	June 30,		December 31,
	2018		2017
	(In thousands)
Coal	$	72,268	$	54,692
Repair parts and supplies	84,937		74,268
	$	157,205	$	128,960

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $0.9 million at June 30, 2018 and $0.3 million at December 31, 2017 .

6. Investments in Available-for-Sale Securities

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

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



	June 30, 2018
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
U.S. government and agency securities	$	88,858	$	3	$	(161	)	$	88,700	$	88,700	$	—
Corporate notes and bonds	72,516		3		(325		)	72,194		72,194		—
Total Investments	$	161,374	$	6	$	(486	)	$	160,894	$	160,894	$	—

Table of Contents



	December 31, 2017
										Balance Sheet
										Classification
			Gross Unrealized					Fair		Short-Term		Other
	Cost Basis		Gains		Losses			Value		Investments		Assets
	(In thousands)
Available-for-sale:
U.S. government and agency securities	$	64,151	$	22	$	(73	)	$	64,100	$	64,100	$	—
Corporate notes and bonds	92,038		—		(292		)	91,746		91,746		—
Total Investments	$	156,189	$	22	$	(365	)	$	155,846	$	155,846	$	—

The aggregate fair value of investments with unrealized losses that were owned for less than a year was $128.1 million and $132.0 million at June 30, 2018 and December 31, 2017 , respectively. The aggregate fair value of investments with unrealized losses that were owned for over a year was $17.5 million and $0.0 million at June 30, 2018 and December 31, 2017 , respectively. The unrealized losses in the Company’s portfolio at June 30, 2018 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, 2018 have maturity dates ranging from the third quarter of 2018 through the fourth quarter of 2019 . 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.

7. Sales Contracts

The sales contracts reflected in the Condensed Consolidated Balance Sheets are as follows:



	June 30, 2018								December 31, 2017
	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	(91,650		)	(30,570		)			(84,760		)	(29,979		)
Total	$	5,546		$	1,172		$	4,374	$	12,436		$	1,763		$	10,673
Balance Sheet classification:
Other current	$	5,544		$	634				$	12,432		$	934
Other noncurrent	$	2		$	538				$	4		$	829

The Company anticipates the majority of the remaining net book value of sale contracts to be amortized in 2018 based upon expected shipments.

Table of Contents

8. Derivatives

Interest rate risk management

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

Diesel fuel price risk management

The Company is exposed to price risk with respect to diesel fuel purchased for use in its operations. The Company anticipates purchasing approximately 40 to 47 million gallons of diesel fuel for use in its operations during 2018 . 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, 2018 , the Company had protected the price of approximately 70% of its expected diesel fuel purchases for the remainder of 2018 at an average strike price of $2.10 per gallon. Additionally, the Company has protected approximately 50% of its expected first half 2019 purchases with call options with an average strike price of $2.33 per gallon. At June 30, 2018 , the Company had outstanding heating oil call options for approximately 26 million gallons for the purpose of managing the price risk associated with future diesel purchases. These positions are not designated as hedges for accounting purposes, and therefore, changes in the fair value are recorded immediately to earnings.

Coal price risk management positions

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

At June 30, 2018 , the Company held derivatives for risk management purposes that are expected to settle in the following years:



(Tons in thousands)	2018	2019	Total
Coal sales	1,089	1,587	2,676
Coal purchases	433	79	512

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

Coal trading positions

The Company may sell or purchase forward contracts, swaps and options in the over-the-counter coal market for trading purposes. The Company is exposed to the risk of changes in coal prices on the value of its coal trading portfolio. The estimated future realization of the value of the trading portfolio is $0.4 million of losses during the remainder of 2018 and an immaterial amount of gains during 2019 .

Table of Contents

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, 2018									December 31, 2017
Fair Value of Derivatives	Asset			Liability						Asset			Liability
(In thousands)	Derivative			Derivative						Derivative			Derivative
Derivatives Designated as Hedging Instruments
Coal	$	1,763		$	(9,388	)				$	942		$	(2,146	)

Derivatives Not Designated as Hedging Instruments
Heating oil -- diesel purchases	6,652			—						5,354			—
Coal -- held for trading purposes	35,894			(36,323		)				44,088			(45,221		)
Coal -- risk management	6,058			(22,900		)				5,139			(9,892		)
Natural gas	42			—						27			—
Total	48,646			(59,223		)				54,608			(55,113		)
Total derivatives	50,409			(68,611		)				55,550			(57,259		)
Effect of counterparty netting	(42,542		)	42,542						(50,042		)	50,042
Net derivatives as classified in the balance sheets	$	7,867		$	(26,069	)	$	(18,202	)	$	5,508		$	(7,217	)	$	(1,709	)



		June 30, 2018			December 31, 2017
Net derivatives as reflected on the balance sheets (in thousands)
Heating oil and coal	Other current assets	$	7,867		$	5,508
Coal	Accrued expenses and other current liabilities	(26,069		)	(7,217		)
		$	(18,202	)	$	(1,709	)

The Company had a current asset representing cash collateral posted to a margin account for derivative positions primarily related to coal derivatives of $41.1 million and $16.2 million at June 30, 2018 and December 31, 2017 , 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.

Table of Contents

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)
		2018			2017			2018		2017
Coal sales	(1)	$	(15,462	)	$	49		$	—	$	—
Coal purchases	(2)	2,705			(34		)	—		—
Totals		$	(12,757	)	$	15		$	—	$	—

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, 2018 and 2017 .

Derivatives Not Designated as Hedging Instruments (in thousands)

Three Months Ended June 30,



		Gain (Loss) Recognized
		2018			2017
Coal trading — realized and unrealized	(3)	$	384		$	(836	)
Coal risk management — unrealized	(3)	$	(15,505	)	$	—
Natural gas trading— realized and unrealized	(3)	$	(17	)	$	(27	)
Change in fair value of coal derivatives and coal trading activities, net total		$	(15,138	)	$	(863	)

Coal risk management— realized	(4)	$	(1,649	)	$	—
Heating oil — diesel purchases	(4)	$	3,657		$	(1,147	)

____________________________________________________________

Location in statement of operations:

(1) — Revenues

(2) — Cost of sales

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

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

Derivatives used in Cash Flow Hedging Relationships (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized in Other Comprehensive Income (Effective Portion)						Gains (Losses) Reclassified from Other Comprehensive Income into Income (Effective Portion)
		2018			2017			2018		2017
Coal sales	(1)	$	(10,231	)	$	269		$	—	$	—
Coal purchases	(2)	2,163			(234		)	—		—
Totals		$	(8,068	)	$	35		$	—	$	—

Table of Contents

Derivatives Not Designated as Hedging Instruments (in thousands)

Six Months Ended June 30,



		Gain (Loss) Recognized
		2018			2017
Coal trading — realized and unrealized	(3)	$	942		$	(1,494	)
Coal risk management — unrealized	(3)	$	(12,630	)	$	26
Natural gas trading— realized and unrealized	(3)	$	(36	)	$	(249	)
Change in fair value of coal derivatives and coal trading activities, net total		$	(11,724	)	$	(1,717	)

Coal risk management— realized	(4)	$	(2,680	)	$	—
Heating oil — diesel purchases	(4)	$	3,675		$	(4,725	)

____________________________________________________________

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, 2018 , 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 losses of approximately $7.5 million .

9. Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist of the following:



	June 30,		December 31,
	2018		2017
	(In thousands)
Payroll and employee benefits	$	41,627	$	53,149
Taxes other than income taxes	78,501		77,017
Interest	204		246
Acquired sales contracts	634		934
Workers’ compensation	19,664		18,782
Asset retirement obligations	19,840		19,840
Other	34,260		14,193
	$	194,730	$	184,161

Table of Contents

10.

Debt and Financing Arrangements



	June 30,			December 31,
	2018			2017
	(In thousands)
Term loan due 2024 ($296.3 million face value)	$	295,029		$	296,435
Other	29,280			36,514
Debt issuance costs	(6,619		)	(7,032		)
	317,690			325,917
Less: current maturities of debt	12,533			15,783
Long-term debt	$	305,157		$	310,134

Term Loan Facility

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

On September 25, 2017, the Company entered into the First Amendment (the “First Amendment”) to its Credit Agreement. The First Amendment reduced the interest rate on the $300 million Term Loan Debt Facility to, at the option of Arch Coal, either (i) the London interbank offered rate (“LIBOR”) plus an applicable margin of 3.25% , subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 2.25% . The First Amendment also reset the 1.00% call premium to apply to repricing events that occur on or prior to March 26, 2018.

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

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

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

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

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

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

Table of Contents

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.

Second Amendment to Term Loan Facility

On April 3, 2018, the Company entered into the Second Amendment (the “Second Amendment”) to its Credit Agreement. The Second Amendment further reduces the interest rate on its Term Loan Debt Facility to, at the option of Arch Coal, either (i) the London interbank offered rate (“LIBOR”) plus an applicable margin of 2.75% , subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 1.75% . The Second Amendment also resets the 1.00% call premium to apply to repricing events that occur on or prior to October 3, 2018. The LIBOR floor remains at 1.00% . There is no change to the maturities as a result of the Second Amendment.

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 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, 2018 , letters of credit totaling $75.3 million were outstanding under the facility which had a borrowing base of $79.5 million. As a result, there was no cash collateral required to be posted in the facility.

Inventory-Based Revolving Credit Facility

On April 27, 2017, the Company and certain subsidiaries of Arch Coal entered into a senior secured inventory-based revolving credit facility in an aggregate principal amount of $40 million (the “Inventory Facility”) with Regions Bank (“Regions”) as administrative agent and collateral agent, as lender and swingline lender (in such capacities, the “ Lender ”) and as letter of credit issuer. Availability under the Inventory Facility is subject to a borrowing base consisting of (i) 85% of the net orderly liquidation value of eligible coal inventory, (ii) the lesser of (x) 85% of the net orderly liquidation value of eligible parts and supplies inventory and (y) 35% of the amount determined pursuant to clause (i), and (iii) 100% of Arch Coal’s Eligible Cash (defined in the Inventory Facility), subject to reduction for reserves imposed by Regions.

The commitments under the 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 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 Inventory Facility bear interest at a per annum rate equal to, at the option of Arch Coal, either the base rate or the London interbank offered rate plus, in each case, a margin ranging from 2.25% 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 Inventory Facility are subject to a fee in an amount equal to the applicable margin for LIBOR loans, plus customary fronting and issuance fees.

All existing and future direct and indirect domestic subsidiaries of Arch Coal, subject to customary exceptions, will either constitute co-borrowers under or guarantors of the Inventory Facility (collectively with Arch Coal, the “Loan Parties”). The

Table of Contents

Inventory Facility is secured by first priority security interests in the ABL Priority Collateral (defined in the Inventory Facility) of the Loan Parties and second priority security interests in substantially all other assets of the Loan Parties, subject to customary exceptions (including an exception for the collateral that secures the Extended Securitization Facility).

Arch Coal has the right to prepay borrowings under the Inventory Facility at any time and from time to time in whole or in part without premium or penalty, upon written notice, except that any prepayment of such borrowings that bear interest at the LIBOR rate other than at the end of the applicable interest periods therefore shall be made with reimbursement for any funding losses and redeployment costs of the Lender resulting therefrom.

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

The Inventory Facility contains certain customary affirmative and negative covenants; events of default, subject to customary thresholds and exceptions; and representations, including certain cash management and reporting requirements that are customary for asset-based credit facilities. The Inventory Facility also includes a requirement to maintain Liquidity equal to or exceeding $175 million at all times. As of June 30, 2018 , letters of credit totaling $35.2 million were outstanding under the facility with $4.8 million available 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 2.75% which is the spread on the revised LIBOR term loan. In the event that an interest rate swap is terminated prior to maturity, gains or losses in accumulated other comprehensive income will remain deferred and reclassified into earnings in the periods which the hedged forecasted transaction affects earnings.

Below is a summary of the Company’s outstanding interest rate swap agreements designated as hedges as of June 30, 2018 :



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

$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, 2018 is an asset of $4.2 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 Company realized $0.3 million and $0.5 million of gains during the three and six months ended June 30, 2018 , respectively, related to settlements of the interest rate swaps which was recorded to interest expense on the Company’s Condensed Consolidated Income Statements. The interest rate swaps are classified as level 2 within the fair value hierarchy.

Financing Costs

The Company paid $0.5 million of financing costs during the six months ended June 30, 2018 related to the Second Amendment to the Term Loan Facility discussed above. During the six months ended June 30, 2017 , the Company paid $8.9 million of financing costs primarily related to the issuance of the Term Loan Debt facility discussed above. These issuance costs were capitalized and amortized using the effective interest method over the term of the facility.

Table of Contents

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 related to the extinguishment of its previously existing first lien debt facility and initial efforts to replace the accounts receivable securitization facility.

11. 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:



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In thousands)
Income tax provision (benefit) at statutory rate	$	8,387		$	13,118		$	20,870		$	31,496
Percentage depletion allowance	(2,488		)	(5,692		)	(7,095		)	(12,731		)
State taxes, net of effect of federal taxes	583			408			1,337			891
Change in valuation allowance	(7,317		)	(8,316		)	(17,956		)	(20,218		)
Other, net	(2,531		)	801			(1,066		)	1,721
Provision for (benefit from) income taxes	$	(3,366	)	$	319		$	(3,910	)	$	1,159

The tax provision for the three and six months ended June 30, 2018 includes a $3.3 million release of a FIN 48 reserve for an Australian tax exposure due to the expiration of the local country statute.

On December 22, 2017 the Tax Cut and Jobs Act of 2017 (the “Act”) was signed into law making significant changes to the Internal Revenue Code. Changes include, but are not limited to, a corporate tax rate decrease from 35% to 21% effective for tax years beginning after December 31, 2017, the elimination of the corporate alternative minimum tax regime effective for tax years beginning after December 31, 2017, implementation of a process whereby corporations with unused alternative minimum tax credits will be refunded during 2018-2022, the transition of U.S. international taxation from a worldwide tax system to a territorial system, a one-time transition tax on the mandatory deemed repatriation of cumulative foreign earnings as of December 31, 2017, further limitation on the deductibility of certain executive compensation, allowance for immediate capital expensing of certain qualified property, and limitations on the amount of interest expense deductible beginning in 2018.

The Company has not completed its analysis for the income tax effects of the Act but has provided its best estimate of the impact of the Act for 2017 in its year-end income tax provision in accordance with the guidance and interpretations available at that time as provided under SAB 118. The Company has also recorded provisional adjustments under SAB 118 as part of the forecasted effective tax rate for 2018. The Company will finalize the analysis for the estimate by December 22, 2018, within the one year measurement period under SAB 118.

Table of Contents

12. Fair Value Measurements

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

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

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

· Level 3 is defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. These include the Company’s commodity option contracts (coal, natural gas and heating oil) valued using modeling techniques, such as Black-Scholes, that require the use of inputs, particularly volatility, that are rarely observable. Changes in the unobservable inputs would not have a significant impact on the reported Level 3 fair values at June 30, 2018 .

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, 2018
	Total		Level 1		Level 2		Level 3
	(In thousands)
Assets:
Investments in marketable securities	$	160,894	$	54,832	$	106,062	$	—
Derivatives	12,031		593		4,786		6,652
Total assets	$	172,925	$	55,425	$	110,848	$	6,652
Liabilities:
Derivatives	$	26,069	$	24,862	$	638	$	569

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, 2018			Six Months Ended June 30, 2018
	(In thousands)
Balance, beginning of period	$	4,969		$	5,426
Realized and unrealized gains recognized in earnings, net	3,628			3,653
Purchases	823			1,656
Issuances	(580		)	(654		)
Settlements	(2,757		)	(3,998		)
Ending balance	$	6,083		$	6,083

Table of Contents

Net unrealized gains of $1.5 million and $3.0 million were recognized in the Condensed Consolidated Income Statements within Other operating income, net during the three and six months ended June 30, 2018 , respectively, related to Level 3 financial instruments held on June 30, 2018 .

Fair Value of Long-Term Debt

At June 30, 2018 and December 31, 2017 , the fair value of the Company’s debt, including amounts classified as current, was $327.1 million and $336.1 million , respectively. Fair values are based upon observed prices in an active market, when available, or from valuation models using market information, which fall into Level 2 in the fair value hierarchy.

13. Earnings per Common Share

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

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



	Three Months Ended June 30,		Six Months Ended June 30,
	2018	2017	2018	2017
	(In thousands)
Weighted average shares outstanding:
Basic weighted average shares outstanding	20,156	24,659	20,529	24,834
Effect of dilutive securities	880	423	927	411

Diluted weighted average shares outstanding	21,036	25,082	21,456	25,245

Table of Contents

14. Workers Compensation Expense

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

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

Workers’ compensation expense consists of the following components:



	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In thousands)
Self-insured occupational disease benefits:
Service cost	$	1,860	$	1,559	$	3,720	$	3,117
Interest cost ⁽¹⁾	1,194		1,168		2,389		2,337
Total occupational disease	$	3,054	$	2,727	$	6,109	$	5,454
Traumatic injury claims and assessments	2,188		2,532		5,199		5,410
Total workers’ compensation expense	$	5,242	$	5,259	$	11,308	$	10,864

(1) In accordance with the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” these costs are recorded within Nonoperating expenses in the Condensed Consolidated Income Statements on the line item “Non-service related pension and postretirement benefit costs.” For additional information about the adoption of the standard, see Note 2 , “ Accounting Policies ” in the Condensed Consolidated Financial Statements.

15. Employee Benefit Plans

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In thousands)
Interest cost ⁽¹⁾	$	2,270		$	2,991		$	4,541		$	5,982
Expected return on plan assets ⁽¹⁾	(3,080		)	(4,499		)	(6,161		)	(8,996		)
Pension settlement ⁽¹⁾	(1,371		)	(487		)	(1,371		)	(487		)
Net benefit credit	$	(2,181	)	$	(1,995	)	$	(2,991	)	$	(3,501	)

During the second quarter of 2018, 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 plan liability which reduced the liability by approximately $5.0 million with the offset to accumulated other comprehensive income. The discount rate used for the revaluation was 4.11% .

Table of Contents

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



	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In thousands)
Service cost	$	139	$	171	$	279	$	341
Interest cost ⁽¹⁾	919		1,059		1,837		2,117
Net benefit cost	$	1,058	$	1,230	$	2,116	$	2,458

16. Commitments and Contingencies

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

In addition, the Company is a party to numerous other claims and lawsuits with respect to various matters. As of June 30, 2018 and December 31, 2017 , the Company had accrued $0.4 million and $0.2 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.

Table of Contents

17. Segment Information

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

On September 14, 2017, the Company closed on its’ definitive agreement to sell Lone Mountain Processing LLC, an operating mine complex within the Company’s metallurgical coal segment. Through this transaction the Company divested all active operations in the states of Kentucky and Virginia.

Operating segment results for the three and six months ended June 30, 2018 and 2017 , are presented below. The Company measures its segments based on “adjusted earnings before interest, taxes, depreciation, depletion, amortization, accretion on asset retirements obligations, and nonoperating expenses (Adjusted EBITDA).” Adjusted EBITDA does not reflect mine closure or impairment costs, since those are not reflected in the operating income reviewed by management. The Corporate, Other and Eliminations grouping includes these charges, as well as the change in fair value of coal derivatives and coal trading activities, net; corporate overhead; land management activities; other support functions; and the elimination of intercompany transactions.

Table of Contents



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

Three Months Ended June 30, 2017
Revenues	$	230,579	$	227,649	$	91,639	$	(1	)	$	549,866
Adjusted EBITDA	31,789		62,552		26,910		(25,651		)	95,600
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
Total assets	426,793		580,543		126,870		997,852			2,132,058
Capital expenditures	822		6,825		1,899		1,426			10,972

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

Six Months Ended June 30, 2017
Revenues	$	504,007	$	453,232	$	193,545	$	57		$	1,150,841
Adjusted EBITDA	79,794		130,862		54,152		(47,989		)	216,819
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
Total assets	426,793		580,543		126,870		997,852			2,132,058
Capital expenditures	950		11,436		2,640		1,896			16,922

Table of Contents

A reconciliation of net income to adjusted EBITDA follows:



	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018			2017
	(In thousands)
Net income	$	43,306		$	37,160	$	103,291		$	88,828
Provision for (benefit from) income taxes	$	(3,366	)	$	319	$	(3,910	)	$	1,159
Interest expense, net	3,498			5,161		7,620			14,059
Depreciation, depletion and amortization	30,549			30,701		60,252			62,622
Accretion on asset retirement obligations	6,993			7,623		13,985			15,246
Amortization of sales contracts, net	3,248			14,352		6,299			29,042
Net loss resulting from early retirement of debt and debt restructuring	485			31		485			2,061
Non-service related pension and postretirement benefit costs	(68		)	232		1,235			953
Reorganization items, net	740			21		1,041			2,849
Adjusted EBITDA	$	85,385		$	95,600	$	190,298		$	216,819

Table of Contents

18. Revenue Recognition

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

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



	PRB		MET		Other Thermal		Corporate, Other and Eliminations			Consolidated
	(in thousands)
Three Months Ended June 30, 2018
North America revenues	$	229,035	$	38,323	$	40,547	$	3,625		$	311,530
Seaborne revenues	843		220,709		59,267		—			280,819

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

Three Months Ended June 30, 2017
North America revenues	$	230,579	$	82,498	$	71,539	$	(1	)	$	384,615
Seaborne revenues	—		145,151		20,100		—			165,251

Total revenues	$	230,579	$	227,649	$	91,639	$	(1	)	$	549,866



	PRB		MET		Other Thermal		Corporate, Other and Eliminations		Consolidated
	(in thousands)
Six Months Ended June 30, 2018
North America revenues	$	473,395	$	68,001	$	84,214	$	3,625	$	629,235
Seaborne revenues	1,911		429,378		107,120		—		538,409

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

Six Months Ended June 30, 2017
North America revenues	$	504,007	$	151,233	$	140,503	$	57	$	795,800
Seaborne revenues	—		301,999		53,042		—		355,041

Total revenues	$	504,007	$	453,232	$	193,545	$	57	$	1,150,841

As of June 30, 2018 , the Company has outstanding performance obligations for the remainder of 2018 of 35.0 million tons of fixed price contracts and 4.9 million tons of variable price contracts. Additionally, the Company has outstanding performance obligations beyond 2018 of approximately 70.8 million tons of fixed price contracts and 6.4 million tons of variable price contracts.

Table of Contents

19. Subsequent Events

On July 26, 2018, the board of directors of Arch Coal authorized an incremental $250 million increase to the share repurchase program bringing the total authorization to $750 million . The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on a number of factors, including business and market conditions, our future financial performance, and other capital priorities. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements. As of June 30, 2018 , we had repurchased 5,344,411 shares at an average share price of $78.40 per share for an aggregate purchase price of approximately $419 million since inception of the stock repurchase program. The Company had 19,587,748 common shares outstanding as of July 27, 2018 .

The purchases under the share repurchase program may be made in the open market or through privately negotiated transactions from time to time and in accordance with applicable laws, rules and regulations. Repurchases may also be made pursuant to a Rule 10b5-1 plan, which permits shares to be repurchased in accordance with pre-determined criteria when the Company might otherwise be prohibited from doing so under insider trading laws or because of self-imposed trading blackout periods. 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 Company’s stock price and other market conditions.

Table of Contents

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

Cautionary Notice Regarding Forward-Looking Statements

This report contains “forward-looking statements” - that is, statements related to future, not past, events. In this context, forward-looking statements often address our expected future business and financial performance, and often contain words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” or “will.” Forward-looking statements by their nature address matters that are, to different degrees, uncertain. For us, particular uncertainties arise from changes in the demand for our coal by the electric generation and steel industries; from legislation and regulations relating to the Clean Air Act and other environmental initiatives; from operational, geological, permit, labor and weather-related factors, from the Tax Cuts and Jobs Act and other tax reforms; from the effects of foreign and domestic trade policies, actions or disputes; from fluctuations in the amount of cash we generate from operations which could impact, among other things, our ability to pay dividends of repurchase shares in accordance with our announced capital allocation plan; from future integration of acquired businesses; and from numerous other matters of national, regional and global scale, including those of a political, economic, business, competitive or regulatory nature. These uncertainties may cause our actual future results to be materially different than those expressed in our forward-looking statements. We do not undertake to update our forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by law. For a more detailed description of some of the risks and uncertainties that may affect our future results, you should see the “Risk Factors” in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2017 .

Overview

Our results for the second quarter of 2018 benefited from continued strength in the metallurgical and international thermal markets, and favorable weather patterns for electricity generation in the challenging domestic thermal market. While natural gas storage levels remain significantly below both year ago and five year average levels, natural gas production levels have increased meaningfully and strong oil prices have resulted in significantly higher associated gas output. Pricing for the competing fuel was marginally lower year over year, while remaining effectively flat during the current quarter. Generator coal stockpiles continued to decline and are approaching historically normal levels based on days of burn. Powder River Basin coal remained economically competitive for electrical generation in many regions throughout the country during the current quarter, and our Powder River Basin operations were able to effectively mitigate the impact of excessive rainfall in the basin late in the current quarter. Pricing in international thermal markets strengthened throughout the current quarter, approaching multi-year highs by the end of the period. Certain of our operations continued to economically ship coal into these markets throughout the current quarter, and we continued to layer in forward positions in these markets at economically viable levels.

Metallurgical coal markets remained strong in the second quarter of 2018 , as economic growth and certain supply constraints continued to support international coking coal prices. During the current period, pricing differentials between the Atlantic and Pacific seaborne markets converged, and by the middle of the quarter, pricing for the Pacific market again exceeded pricing in the Atlantic coking coal market. We believe both Atlantic and Pacific coking coal markets remain reasonably well balanced, and supported by continued strong global steel demand growth. Additional coking coal supply is coming back into the market from existing and formerly idled operations, particularly in the United States, but overall global investment in new production capacity appears to be limited. While the new steel tariffs appear to have had little impact on coking coal pricing or demand to date, longer term implications for coking coal markets and the global economy as a whole remain less certain.

In the third quarter of 2017 we sold our Lone Mountain operation, which had been part of our Metallurgical segment. Lone Mountain is included in both the first six months and second quarter of 2017 results presented herein.

Table of Contents

Results of Operations

Three Months Ended June 30, 2018 and 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 months ended June 30, 2018 and 2017 :



	Three Months Ended June 30,
	2018		2017		(Decrease) / Increase
	(In thousands)
Coal sales	$	592,349	$	549,866	$	42,483
Tons sold	22,952		22,521		431

On a consolidated basis, coal sales in the second quarter of 2018 was approximately $42.5 million or 7.7% greater than in the second quarter 2017 , and tons sold increased approximately 0.4 million tons or 1.9%. Coal sales from ongoing Metallurgical operations increased approximately $64.4 million on increased pricing and volume, with pricing accounting for approximately two thirds of the increase. Powder River Basin coal sales decreased slightly as decreased pricing was largely offset by increased volume, and Other Thermal coal sales increased approximately $8.2 million as increased pricing was partially offset by reduced volume. Lone Mountain, an operation that we divested in 2017, provided approximately $33.0 million in coal sales in the prior year period. See discussion in “Operational Performance” for further information about segment results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the three months ended June 30, 2018 and 2017 :



	Three Months Ended June 30,
	2018			2017			Increase (Decrease) in Net Income
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	474,388		$	434,465		$	(39,923	)
Depreciation, depletion and amortization	30,549			30,701			152
Accretion on asset retirement obligations	6,993			7,623			630
Amortization of sales contracts, net	3,248			14,352			11,104
Change in fair value of coal derivatives and coal trading activities, net	15,138			863			(14,275		)
Selling, general and administrative expenses	24,756			22,456			(2,300		)
Other operating income, net	(7,318		)	(3,518		)	3,800
Total costs, expenses and other	$	547,754		$	506,942		$	(40,812	)

Cost of sales. Our cost of sales for the second quarter of 2018 increased approximately $39.9 million or 9.2% versus the second quarter of 2017 . The increase consists primarily of transportation costs (approximately $25.4 million), labor related costs (approximately $9.2 million), repairs and supplies (approximately $15.3 million), change in coal inventories (approximately $9.6 million), and purchased coal costs (approximately $8.9 million), at ongoing operations. These cost increases were partially offset by approximately $34.3 million of cost of sales in the prior year period at Lone Mountain, an operation sold in 2017 as discussed in the Overview. See discussion in “Operational Performance” for further information about segment results.

Amortization of sales contracts, net. The decrease in amortization of sales contracts, net in the second quarter of 2018 versus the second quarter of 2017 is primarily related to the value of certain Powder River Basin supply contracts being fully amortized at the end of 2017 .

Change in fair value of coal derivatives and coal trading activities, net. The increased cost in the second quarter of 2018 versus the prior year period is primarily related to mark to market losses on coal derivatives that we have entered to hedge

Table of Contents

our price risk for anticipated international thermal coal shipments. As international thermal markets strengthened during the current quarter, the market value of these positions declined.

Selling, general and administrative expenses. The increase in selling, general and administrative expenses in the second quarter of 2018 versus the second quarter of 2017 is primarily due to compensation costs (approximately $1.8 million) and professional services (approximately $0.4 million).

Other operating income, net . The increased benefit from other operating income, net in the second quarter of 2018 versus the second quarter of 2017 consists primarily of improvement in mark to market adjustments on heating oil derivatives (approximately $4.8 million), partially offset by the unfavorable impact of coal derivative settlements in the current period (approximately $1.6 million).

Nonoperating Expense. The following table summarizes our nonoperating expense during the three months ended June 30, 2018 and 2017 :



	Three Months Ended June 30,
	2018			2017			Increase (Decrease) in Net Income
	(In thousands)
Non-service related pension and postretirement benefit (costs) credits	$	68		$	(232	)	$	300
Net loss resulting from early retirement of debt and debt restructuring	(485		)	(31		)	(454		)
Reorganization items, net	(740		)	(21		)	(719		)
Total nonoperating expense	$	(1,157	)	$	(284	)	$	(873	)

Nonoperating expenses increased in the second quarter of 2018 versus the second quarter of 2017 primarily due to an increase in Chapter 11 reorganization costs and costs associated with the repricing of our term loan in the current period. Additionally, we adopted ASU 2017-07, “Compensation-Retirement Benefits (Topic 715) Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and now reflect these costs as nonoperating expenses. See further discussion in Note 2, “Accounting Policies,” and Note 10, “Debt and Financing Arrangements,” to the Condensed Consolidated Financial Statements.

Provision for (benefit from) income taxes . The following table summarizes our provision for (benefit from) income taxes during the three months ended June 30, 2018 and 2017 :



	Three Months Ended June 30,
	2018			2017		Increase (Decrease) in Net Income
	(In thousands)
Provision for (benefit from) income taxes	$	(3,366	)	$	319	$	3,685

See further discussion in Note 11 , “Income Taxes,” to the Condensed Consolidated Financial Statements.

Table of Contents

Six Months Ended June 30, 2018 and 2017

Coal Sales. The following table summarizes information about our coal sales during the six months ended June 30, 2018 and 2017 :



	Six Months Ended June 30,
	2018		2017		(Decrease) / Increase
	(In thousands)
Coal sales	$	1,167,644	$	1,150,841	$	16,803
Tons sold	46,616		48,199		(1,583		)

On a consolidated basis, coal sales in the first six months of 2018 was approximately $16.8 million or 1.5% greater than in the first six months 2017 , and tons sold declined approximately 1.6 million tons or 3.3%. Coal sales from ongoing Metallurgical operations increased approximately $100.5 million on increased pricing and volume, with pricing accounting for approximately 84% of the increase. Powder River Basin coal sales declined approximately $28.7 million on reduced volume and price, and Other Thermal declined approximately $2.2 million on reduced volume partially offset by increased pricing. Lone Mountain, an operation sold in 2017 as discussed in the Overview, provided approximately $56.3 million in coal sales in the prior year period. See discussion in “Operational Performance” for further information about segment results.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income during the six months ended June 30, 2018 and 2017 :



	Six Months Ended June 30,
	2018			2017			Increase (Decrease) in Net Income
	(In thousands)
Cost of sales (exclusive of items shown separately below)	$	929,168		$	894,915		$	(34,253	)
Depreciation, depletion and amortization	60,252			62,622			2,370
Accretion on asset retirement obligations	13,985			15,246			1,261
Amortization of sales contracts, net	6,299			29,042			22,743
Change in fair value of coal derivatives and coal trading activities, net	11,724			1,717			(10,007		)
Selling, general and administrative expenses	50,704			43,218			(7,486		)
Other operating income, net	(14,250		)	(5,828		)	8,422
Total costs, expenses and other	$	1,057,882		$	1,040,932		$	(16,950	)

Cost of sales. Our cost of sales for the first six months of 2018 increased approximately $34.3 million or 3.8% versus the first six months of 2017 . The increase consists primarily of transportation costs (approximately $15.7 million), labor related costs (approximately $20.4 million), repairs and supplies (approximately $24.2 million), change in coal inventories (approximately $9.1 million), and purchased coal costs (approximately $13.9 million) at ongoing operations. These cost increases were partially offset by approximately $55.9 million of cost of sales in the prior year period at Lone Mountain, an operation sold in 2017 as discussed in the Overview. See discussion in “Operational Performance” for further information about segment results.

Amortization of sales contracts, net. The decrease in amortization of sales contracts, net in the first six months of 2018 versus the first six months of 2017 is primarily related to the value of certain Powder River Basin supply contracts being fully amortized at the end of 2017 .

Change in fair value of coal derivatives and coal trading activities, net. The increased cost in the first six months of 2018 versus the prior year period is primarily related to mark to market losses on coal derivatives that we have entered to hedge our price risk for anticipated international thermal coal shipments. As international thermal markets strengthened during the current period, the market value of these positions declined.

Table of Contents

Selling, general and administrative expenses. The increase in selling, general and administrative expenses in the first six months of 2018 versus the first six months of 2017 is primarily due to compensation costs (approximately $5.4 million) and professional services (approximately $2.0 million).

Other operating income, net . The increased benefit from other operating income, net in the first six months of 2018 versus the second quarter of 2017 consists primarily of improvement in mark to market adjustments on heating oil derivatives (approximately $8.4 million), increased miscellaneous revenues including outlease royalty income, transloading fees, and net gains on asset sales (approximately $2.0 million), and increased income from equity investments (approximately $1.1 million), partially offset by the unfavorable impact of coal derivative settlements in the current period (approximately $2.7 million).

Nonoperating Expense. The following table summarizes our nonoperating expense during the six months ended June 30, 2018 and 2017 :



	Six Months Ended June 30,
	2018			2017			Increase (Decrease) in Net Income
	(In thousands)
Non-service related pension and postretirement benefit (costs) credits	$	(1,235	)	$	(953	)	$	(282	)
Net loss resulting from early retirement of debt and debt restructuring	(485		)	(2,061		)	1,576
Reorganization items, net	(1,041		)	(2,849		)	1,808
Total nonoperating expense	$	(2,761	)	$	(5,863	)	$	3,102

Nonoperating expenses declined in the first six months of 2018 versus the first six months of 2017 primarily due to costs associated with our efforts to replace our securitization facility and term loan in the prior year period, partially offset by costs associated with the second repricing of our term loan in the current period, and reduced expenses associated with our Chapter 11 reorganization. Additionally, we adopted ASU 2017-07, “Compensation-Retirement Benefits (Topic 715) Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and now reflect these costs as nonoperating expenses. See further discussion in Note 2, “Accounting Policies,” and Note 10, “Debt and Financing Arrangements,” to the Condensed Consolidated Financial Statements.

Provision for (benefit from) income taxes . The following table summarizes our provision for (benefit from) income taxes during the six months ended June 30, 2018 and 2017 :



	Six Months Ended June 30,
	2018			2017		Increase (Decrease) in Net Income
	(In thousands)
Provision for (benefit from) income taxes	$	(3,910	)	$	1,159	$	5,069

See further discussion in Note 11 , “Income Taxes,” to the Condensed Consolidated Financial Statements.

Table of Contents

Operational Performance

Three and Six Months Ended June 30, 2018 and 2017

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

The following table shows results by operating segment for the three and six months ended June 30, 2018 and June 30, 2017 .



	Three Months Ended June 30,							Six Months Ended June 30,
	2018		2017		Variance			2018		2017		Variance
Powder River Basin
Tons sold (in thousands)	18,792		18,092		700			38,535		39,418		(883		)
Coal sales per ton sold	$	12.06	$	12.55	$	(0.49	)	$	12.11	$	12.56	$	(0.45	)
Cash cost per ton sold	$	10.66	$	10.82	$	0.16		$	10.72	$	10.55	$	(0.17	)
Cash margin per ton sold	$	1.40	$	1.73	$	(0.33	)	$	1.39	$	2.01	$	(0.62	)
Adjusted EBITDA (in thousands)	$	26,491	$	31,789	$	(5,298	)	$	53,993	$	79,794	$	(25,801	)
Metallurgical
Tons sold (in thousands)	2,009		2,104		(95		)	3,764		4,164		(400		)
Coal sales per ton sold	$	104.38	$	90.59	$	13.79		$	109.78	$	90.72	$	19.06
Cash cost per ton sold	$	61.33	$	60.95	$	(0.38	)	$	64.59	$	59.33	$	(5.26	)
Cash margin per ton sold	$	43.05	$	29.64	$	13.41		$	45.19	$	31.39	$	13.80
Adjusted EBITDA (in thousands)	$	86,657	$	62,552	$	24,105		$	170,399	$	130,862	$	39,537
Other Thermal
Tons sold (in thousands)	2,036		2,325		(289		)	4,203		4,617		(414		)
Coal sales per ton sold	$	36.77	$	33.41	$	3.36		$	36.16	$	34.45	$	1.71
Cash cost per ton sold	$	31.19	$	22.06	$	(9.13	)	$	29.82	$	22.93	$	(6.89	)
Cash margin per ton sold	$	5.58	$	11.35	$	(5.77	)	$	6.34	$	11.52	$	(5.18	)
Adjusted EBITDA (in thousands)	$	11,842	$	26,910	$	(15,068	)	$	27,510	$	54,152	$	(26,642	)

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

Powder River Basin — Adjusted EBITDA for the three and six months ended June 30, 2018 , declined from the three and six months ended June 30, 2017 due to reduced pricing in both current periods and reduced volume in the current six month period. Pricing was negatively impacted by lower natural gas pricing, increased wind generation, and excess generator coal stockpiles given reduced coal fired generation. Pricing was also negatively impacted by the normal year end roll off and replacement of term contracts that had been executed during stronger market environments. Volume increased year over year in the current three month period as weather patterns were favorable for electric generation and our operations were able to largely avoid negative impacts from heavy rains in the mining area during June of the current year. Cash cost per ton sold improved in the three months ended June 30, 2018 versus the three months ended June 30, 2017 due to the volume improvement, partially offset by increased commodity costs, particularly fuel. Cash cost per ton sold for the current six month period was negatively impacted by reduced volume, and by increased commodity costs, particularly fuel. These cost pressures were partially offset by cost control efforts that included reduced maintenance and contractor costs.

Table of Contents

Metallurgical —Adjusted EBITDA for the three and six months ended June 30, 2018 , increased from the three and six months ended June 30, 2017 due to significant pricing improvement. Pricing was supported by the continued strength in international metallurgical markets. Furthermore, our pricing benefited from our decision to commit less of our planned production to North American annual fixed price contracts, leaving a greater portion exposed to stronger pricing in the international markets. Our sales volume decline versus the prior year periods was effectively all related to Lone Mountain, an operation that we divested in 2017. Lone Mountain sold approximately 0.4 million tons and 0.7 million tons in the prior year three and six month periods, respectively. In the three and six months ended June 30, 2018 , tons sold from ongoing operations increased approximately 0.3 million tons versus the three and six months ended June 30, 2017 . Our cash cost per ton sold for the three and six months ended June 30, 2018 increased versus the prior year period due to increased operating tax and royalty costs, increased labor costs across the segment, and some specific nonrecurring expenses primarily associated with difficult geology on the prior longwall panel at Mountain Laurel. In particular, the current six month period cost of sales per ton sold includes $1.9 million to repair subsidence damage to a state road adjacent to our Mountain Laurel operation. Operating taxes and royalties are impacted by the increased coal sales per ton sold and an expected increase in the severance tax rate at our Beckley Mine.

Our metallurgical segment sold 1.7 million tons of coking coal and 0.3 million tons of associated thermal coal in the three months ended June 30, 2018 , as compared to 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 three months ended June 30, 2017 . In the six months ended June 30, 2018 we sold 3.1 million tons of coking coal and 0.6 million tons of associated thermal coal versus 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 six months ended June 30, 2017 . Longwall operations accounted for approximately 69% of our shipment volume in the six months ended June 30, 2018 and 55% of our shipment volume in the six months ended June 30, 2017 .

Other Thermal — Adjusted EBITDA for the three and six months ended June 30, 2018 , declined from the three and six months ended June 30, 2017 due to lower sales volume at West Elk and increased cost at our West Elk and Coal Mac operations. In the current year periods, rail service issues constrained sales volume at both West Elk and Coal Mac. West Elk costs increased due to higher levels of continuous miner production as compared to the prior year period, which was necessary to maintain adequate longwall development. Coal Mac costs increased as maintenance and fuel costs increased.

Table of Contents

Reconciliation of Non-GAAP measures

Segment coal sales per ton sold

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



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

Three Months Ended June 30, 2017	Powder River Basin		Metallurgical		Other Thermal		Idle and Other			Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	230,579	$	227,649	$	91,639	$	(1	)	$	549,866
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		—		—			—
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—		—			—
Transportation costs	3,500		37,025		13,941		—			54,466
Non-GAAP Segment coal sales revenues	$	227,079	$	190,624	$	77,698	$	(1	)	$	495,400
Tons sold	18,092		2,104		2,325
Coal sales per ton sold	$	12.55	$	90.59	$	33.41

Table of Contents




Six Months Ended June 30, 2018	Powder River Basin		Metallurgical		Other Thermal		Idle and Other			Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	475,306	$	497,379	$	191,334	$	3,625		$	1,167,644
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		2,680		—			2,680
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—		3,626			3,626
Transportation costs	8,655		84,192		36,675		—			129,522
Non-GAAP Segment coal sales revenues	$	466,651	$	413,187	$	151,979	$	(1	)	$	1,031,816
Tons sold	38,535		3,764		4,203
Coal sales per ton sold	$	12.11	$	109.78	$	36.16

Six Months Ended June 30, 2017	Powder River Basin		Metallurgical		Other Thermal		Idle and Other			Consolidated
(In thousands)
GAAP Revenues in the consolidated statements of operations	$	504,007	$	453,232	$	193,545	$	57		$	1,150,841
Less: Adjustments to reconcile to Non-GAAP Segment coal sales revenue
Coal risk management derivative settlements classified in "other income"	—		—		—		—			—
Coal sales revenues from idled or otherwise disposed operations and pass through agreements not included in segments	—		—		—		52			52
Transportation costs	8,840		75,496		34,481		7			118,824
Non-GAAP Segment coal sales revenues	$	495,167	$	377,736	$	159,064	$	(2	)	$	1,031,965
Tons sold	39,418		4,164		4,617
Coal sales per ton sold	$	12.56	$	90.72	$	34.45

Table of Contents

Segment cash cost per ton sold

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




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

Three Months Ended June 30, 2017	Powder River Basin			Metallurgical		Other Thermal		Idle and Other		Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	198,274		$	165,272	$	65,242	$	5,677	$	434,465
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	(891		)	—		—		—		(891		)
Transportation costs	3,500			37,025		13,941		—		54,466
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		5,233		5,233
Other (operating overhead, certain actuarial, etc.)	—			—		—		444		444
Non-GAAP Segment cash cost of coal sales	$	195,665		$	128,247	$	51,301	$	—	$	375,213
Tons sold	18,092			2,104		2,325
Cash Cost Per Ton Sold	$	10.82		$	60.95	$	22.06

Table of Contents




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

Six Months Ended June 30, 2017	Powder River Basin			Metallurgical		Other Thermal		Idle and Other			Consolidated
(In thousands)
GAAP Cost of sales in the consolidated statements of operations	$	423,381		$	322,531	$	140,359	$	8,644		$	894,915
Less: Adjustments to reconcile to Non-GAAP Segment cash cost of coal sales
Diesel fuel risk management derivative settlements classified in "other income"	(1,495		)	—		—		—			(1,495		)
Transportation costs	8,840			75,496		34,481		7			118,824
Cost of coal sales from idled or otherwise disposed operations and pass through agreements not included in segments	—			—		—		8,681			8,681
Other (operating overhead, certain actuarial, etc.)	—			—		—		(44		)	(44		)
Non-GAAP Segment cash cost of coal sales	$	416,036		$	247,035	$	105,878	$	—		$	768,949
Tons sold	39,418			4,164		4,617
Cash Cost Per Ton Sold	$	10.55		$	59.33	$	22.93

Table of Contents

Reconciliation of Segment Adjusted EBITDA to Net Income

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In thousands)
Net income	$	43,306		$	37,160		$	103,291		$	88,828
Provision for (benefit from) income taxes	(3,366		)	319			(3,910		)	1,159
Interest expense, net	3,498			5,161			7,620			14,059
Depreciation, depletion and amortization	30,549			30,701			60,252			62,622
Accretion on asset retirement obligations	6,993			7,623			13,985			15,246
Amortization of sales contracts, net	3,248			14,352			6,299			29,042
Net loss resulting from early retirement of debt and debt restructuring	485			31			485			2,061
Non-service related pension and postretirement benefit costs	(68		)	232			1,235			953
Reorganization items, net	740			21			1,041			2,849
Adjusted EBITDA	85,385			95,600			190,298			216,819
EBITDA from idled or otherwise disposed operations	2,832			4,698			5,411			6,934
Selling, general and administrative expenses	24,756			22,456			50,704			43,218
Other	12,017			(1,503		)	5,489			(2,163		)
Segment Adjusted EBITDA from coal operations	$	124,990		$	121,251		$	251,902		$	264,808

O ther includes primarily income from our equity investments 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 ensuring adequate liquidity.

On April 27, 2017, our Board of Directors authorized a share repurchase program for up to $300 million of our common stock. On October 26, 2017, our Board of Directors authorized an additional $200 million for our share repurchase program, bringing the total authorization to $500 million. On July 26, 2018, our Board of Directors authorized an additional $250 million for our share repurchase program, bringing the total authorization to $750 million. During the quarter ended June 30, 2018 , we repurchased 960,105 shares of our stock for approximately $78.3 million of which $77.8 million was paid in the current quarter bringing total repurchases to 5,344,411 shares for approximately $419.0 million. The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on a number of factors, including business and

Table of Contents

market conditions, our future financial performance, and other capital priorities. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements.

On April 27, 2017, our Board of Directors authorized a quarterly common stock cash dividend of $0.35 per share. On February 13, 2018, we announced an increase in the quarterly dividend to $0.40 per share. A dividend of approximately $8.0 million was paid on June 15, 2018 to stockholders of record at the close of business on May 31, 2018, bringing total dividends paid this year to approximately $16.3 million.

Given the volatile nature of coal markets, we believe it is important to take a prudent approach to managing our balance sheet and liquidity. Our dividend policy and share repurchase program will be implemented in a manner that will result in maintaining cash levels similar to those we have seen over the past year. In the future, we will continue to evaluate our capital allocation initiatives in light of the current state of and our outlook for coal markets; the amount of our planned production that has been committed and priced; the capital needs of the business; and other strategic opportunities.

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

The term loans provided under the Term Loan Debt Facility (the “Term Loans”) are subject to quarterly principal amortization payments in an amount equal to $750,000. For further information regarding the Term Loan Debt Facility see Note 10 to the Consolidated Financial Statements “Debt and Financing Arrangements”.

On September 25, 2017, we entered into the First Amendment (the “First Amendment”) to the Term Loan Debt Facility. The First Amendment reduced the interest rate on the Term Loan Debt Facility to, at our option, either (i) the London interbank offered rate (“LIBOR”) plus an applicable margin of 3.25%, subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 2.25%.

On April 3, 2018, we entered into the Second Amendment (the “Second Amendment”) to the Term Loan Debt Facility. The Second Amendment reduced the interest rate on the Term Loan Debt Facility to, at our option, either (i) LIBOR plus an applicable margin of 2.75%, subject to a 1.00% LIBOR floor, or (ii) a base rate plus an applicable margin of 1.75%. There is no change to the maturities as a result of the First Amendment or Second Amendment. The reduction in interest rate is expected to generate incremental annual cash interest savings of $1.5 million. For further information regarding this amendment see Note 10 “Debt and Financing Arrangements” to the Condensed Consolidated Financial Statements.

During the second quarter of 2017, we entered into a series of interest rate swaps to fix a portion of the LIBOR interest payments due under the term loan. As interest payments are made on the term loan, amounts in accumulated other comprehensive income will be reclassified into earnings through interest expense to reflect a net interest on the term loan equal to the effective yield of the fixed rate of the swap plus 3.25% through April 3, 2018 and 2.75% thereafter which is the spread on the LIBOR term loan as amended. For further information regarding the interest rate swaps see Note 10 to the Consolidated Financial Statements “Debt and Financing Arrangements.”

On April 27, 2017, we extended and amended our existing trade accounts receivable securitization facility (the “Extended Securitization Facility”), which supports the issuance of letters of credit and requests for cash advances. The Extended Securitization Facility has borrowing capacity of $160 million and the maturity date is three years after the Securitization Facility Closing Date. As of June 30, 2018, we had letters of credit totaling $75.3 million outstanding under the facility which had a borrowing base of $79.5 million. As a result, we were not required to post cash collateral in the facility. For further information regarding the Extended Securitization Facility see Note 10 to the Consolidated Financial Statements “Debt and Financing Arrangements.”

On April 27, 2017, we entered into a senior secured inventory-based revolving credit facility in an aggregate principal amount of $40 million (the “Inventory Facility”). As of June 30, 2018 , we had letters of credit totaling $35.2 million outstanding under the facility with $4.8 million available for borrowings. For further information regarding the Inventory Facility see Note 10 to the Consolidated Financial Statements “Debt and Financing Arrangements.”

Table of Contents

On June 30, 2018 , we had total liquidity of approximately $420 million including $402 million in cash and equivalents, and short term investments in debt securities, with the remainder provided by availability under our credit facilities, and funds withdrawable from brokerage accounts.

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, 2018 and 2017 :



	Six Months Ended June 30,
	2018			2017
	(In thousands)
Cash provided by (used in):
Operating activities	$	144,996		$	200,799
Investing activities	(35,326		)	(98,210		)
Financing activities	(141,682		)	(103,708		)

Cash Flow

Cash provided by operating activities in the six months ended June 30, 2018 declined from the six months ended June 30, 2017 mainly due to a large unfavorable year over year change in working capital particularly in receivables and payables, and the release of cash deposits held by vendors in the prior year period, partially offset by receipt of an approximately $24 million income tax refund in the current period.

Cash used in investing activities in the six months ended June 30, 2018 declined from the six months ended June 30, 2017 due to reduced net purchases of short term investments of approximately $67 million, and investment in affiliates of approximately $9 million in the prior year period, partially offset by increased capital expenditures of approximately $13 million in the current period.

Cash used in financing activities in the six months ended June 30, 2018 increased from the six months ended June 30, 2017 mainly due to increased purchases of treasury stock of approximately $65 million and increased dividends paid of approximately $8 million, partially offset by the net repayment of the previously existing term loan credit agreement with proceeds from the Term Loan Debt Facility, and financing costs associated with the Term Loan Debt Facility in the prior year period.

Table of Contents

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 2018 and 2019 were as follows as of July 31, 2018 :



	2018			2019
	Tons	$ per ton		Tons	$ per ton
Metallurgical	(in millions)			(in millions)
Committed, North America Priced Coking	1.2	$	97.54	—	$	—
Committed, Seaborne Priced Coking	3.1	$	128.12	—	—
Committed, Seaborne Unpriced Coking	1.5			1.6

Committed, Priced Thermal	1.0	$	32.47	—	$	—
Committed, Unpriced Thermal	—			—

Powder River Basin
Committed, Priced	69.2	$	12.03	34.2	$	12.40
Committed, Unpriced	1.1			2.2

Other Thermal
Committed, Priced	8.6	$	37.10	2.5	$	41.15
Committed, Unpriced	0.1			—

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, 2018 . The estimated future realization of the value of the trading portfolio is $0.4 million of losses during the remainder of 2018 and an immaterial amount of gains during the remainder of 2019 .

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

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

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

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

During the six months ended June 30, 2018 , VaR for our coal trading positions that are recorded at fair value through earnings ranged from under $0.1 million to $0.3 million . The linear mean of each daily VaR was $0.2 million . The final VaR at June 30, 2018 was $0.1 million .

Table of Contents

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, 2018 , VaR for our risk management positions that are recorded at fair value through earnings ranged from $0.5 million to $2.5 million . The linear mean of each daily VaR was $1.5 million . The final VaR at June 30, 2018 was $2.5 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, 2018 . 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.

Table of Contents

PART II

OTHER INFORMATION

Item 1. Legal Proceedings

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

Item 1A. Risk Factors

We may not be able to pay dividends or repurchase shares of our common stock in accordance with our announced intent or at all.

The Board of Directors’ determinations regarding dividends and share repurchases will depend on a variety of factors, including our net income, cash flow generated from operations or other sources, liquidity position and potential alternative uses of cash, such as acquisitions and organic growth opportunities, as well as economic conditions and expected future financial results.

Our ability to declare future dividends and make future share repurchases will depend on our future financial performance, which in turn depends on the successful implementation of our strategy and on financial, competitive, regulatory, technical and other factors, general economic conditions, demand and selling prices for our products and other factors specific to our industry, many of which are beyond our control. Therefore, our ability to generate cash depends on the performance of our operations and could be limited by decreases in our profitability or increases in costs, regulatory changes, capital expenditures or debt servicing requirements.

Any failure to pay dividends or repurchase shares of our common stock could negatively impact our reputation, lessen investor confidence in us, and cause the market price of our common stock to decline.

The effects of foreign and domestic trade policies, actions or disputes on the level of trade among the countries and regions in which we operate could negatively impact our business, financial condition or results of operations.

Tariffs imposed by the current presidential administration could potentially lead to trade disputes with other foreign governments and adversely impact global economic conditions. For instance, in March 2018, the current administration imposed a 25% tariff on all imported steel into the United States which could negatively impact the global demand for steel, and in turn, the demand for metallurgical coal. While the new steel tariffs appear to have had little impact on coking coal pricing or demand to date, longer term implications for coking coal markets and the global economy as a whole remain less certain.

Table of Contents

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. On October 26, 2017, the board of directors approved an incremental $200 million increase to the share repurchase program bringing the total authorization to $500 million. The timing of any future share purchases, and the ultimate number of shares to be purchased, will depend on a number of factors, including business and market conditions, our future financial performance, and other capital priorities. The shares will be acquired in the open market or through private transactions in accordance with Securities and Exchange Commission requirements. The share repurchase program has no termination date, but 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 our stock price and other market conditions.

The table below represents all share repurchases for the three months ended June 30, 2018 :



Date	Total Number Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plan (in thousands)
April 1 through April 30, 2018	186,931	$	88.26	186,931	$	142,804
May 1 through May 31, 2018	592,751	$	79.29	592,751	$	95,805
June 1 through June 30, 2018	180,423	$	81.97	180,423	$	81,016

Total	960,105	$	81.54	960,105

As of June 30, 2018 , we had repurchased 5,344,411 shares at an average share price of $78.40 per share for an aggregate purchase price of approximately $419 million since inception of the stock repurchase program, and the remaining authorized amount for stock repurchases under this program was $81 million.

Item 4. Mine Safety Disclosures.

The statement concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 to this Quarterly Report on Form 10-Q for the period ended June 30, 2018 .

Table of Contents

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		First Amendment to Credit Agreement, dated as of September 25, 2017, among Arch Coal, Inc. as borrower, the lenders from time to time party thereto and Credit Suisse AG, Cayman Islands Branch, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on September 25, 2017).
10.3		Second Amendment to Credit Agreement, dated as of April 3, 2018, among Arch Coal, Inc. as borrower, the lenders from time to time party thereto and Credit Suisse AG, Cayman Islands Branch, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on April 3, 2018).
10.4		Credit Agreement, dated as of April 27, 2017, among Arch Coal, Inc. and certain of its subsidiaries, as borrowers, the lenders from time to time party thereto Regions Bank, in its capacities as administrative agent and as collateral agent (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on May 2, 2017).
10.5		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).
10.6		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).
10.7		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).
10.8		First Amendment to the Second Amended and Restated Purchase and Sale Agreement, dated as of December 21, 2016, among Arch Coal, Inc. and certain subsidiaries of Arch Coal, Inc., as originators (incorporated by reference to Exhibit 10.7 of Arch Coal’s Current Report on Form 8-K filed on October 31, 2017).
10.9		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).
10.10		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).
10.11		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).

Table of Contents



10.12		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).
10.13		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).
10.14		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)
10.15		Coal Lease Agreement dated as of March 31, 1992, among Allegheny Land Company, as lessee, and UAC and Phoenix Coal Corporation, as lessors, and related guarantee (incorporated herein by reference to the Current Report on Form 8-K filed by Ashland Coal, Inc. on April 6, 1992).
10.16		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).
10.17		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).
10.18		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).
10.19		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).
10.20		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).
10.21		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).
1022		C oal 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).
10.23*		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).
10.24*		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).
10.25*		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).
10.26		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).
10.27*		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).
10.28*		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).
10.29*		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).
10.30*		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).
10.31*		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).
10.32		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).
10.33		Stock Repurchase Agreement dated September 13, 2017, among Arch Coal, Inc. and Monarch Alternative Solutions Master Fund Ltd, Monarch Capital Master Partners III LP, MCP Holdings Master LP, Monarch Debt Recovery Master Fund Ltd and P Monarch Recovery Ltd. (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on September 19, 2017).

Table of Contents



10.34		Stock Repurchase Agreement dated December 8, 2017, among Arch Coal, Inc. and Monarch Alternative Solutions Master Fund Ltd, Monarch Capital Master Partners III LP, MCP Holdings Master LP, and Monarch Debt Recovery Master Fund Ltd (incorporated by reference to Exhibit 10.1 of Arch Coal’s Current Report on Form 8-K filed on December 11, 2017).
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, 2018 filed in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed.”

* Denotes a management contract or compensatory plan or arrangement.

Table of Contents

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 31, 2018

TABLE OF CONTENTS

Part I Item 1. Financial Statements Item 2. Management S Discussion and Analysis Of Financial Condition and Results Of Operations Item 3. Quantitative and Qualitative Disclosures About Market Risk Item 4. Controls and Procedures Part II Item 1. Legal Proceedings Item 1A. Risk Factors Item 2. Unregistered Sales Of Equity Securities and Use Of Proceeds Item 4. Mine Safety Disclosures Item 6. Exhibits

Exhibits

10.34 Stock Repurchase Agreement dated December 8, 2017, among Arch Coal, Inc. and Monarch Alternative Solutions Master Fund Ltd, Monarch Capital Master Partners III LP, MCP Holdings Master LP, and Monarch Debt Recovery Master Fund Ltd (incorporated by reference to Exhibit 10.1 of Arch Coals Current Report on Form 8-K filed on December 11, 2017). 31.1 Rule 13a-14(a)/15d-14(a) Certification of John W. Eaves 31.2 Rule13a-14(a)/15d-14(a) Certification of John T. Drexler. 32.1 Section1350 Certification of John W. Eaves. 32.2 Section1350 Certification of John T. Drexler. 95 Mine Safety Disclosure Exhibit.

Supplier name	Ticker
Union Pacific Corporation	UNP
Norfolk Southern Corporation	NSC
Deere & Company	DE
Caterpillar Inc.	CAT
CSX Corporation	CSX
Eaton Corporation plc	ETN
Dover Corporation	DOV
CNH Industrial N.V.	CNHI

ARCH 10-Q Quarter ended June 30, 2018

Exhibits