Table of Contents

 

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

 


 

FORM 10-Q

 

(Mark One)

 

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

 

For the quarterly period ended September 30, 2015

 

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 x  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 x  No o

 

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

 

Large accelerated filer x

 

Accelerated filer o

 

 

 

Non-accelerated filer o

 

Smaller reporting company o

(Do not check if a smaller reporting company)

 

 

 

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

 

At October 20, 2015 there were 21,291,635 shares of the registrant’s common stock outstanding.

 

 

 



Table of Contents

 

TABLE OF CONTENTS

 

 

 

Page

Part I FINANCIAL INFORMATION

3

Item 1. Financial Statements

3

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

30

Item 3. Quantitative and Qualitative Disclosures About Market Risk

40

Item 4. Controls and Procedures

41

Part II OTHER INFORMATION

41

Item 1. Legal Proceedings

41

Item 1A. Risk Factors

44

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

46

Item 4. Mine Safety Disclosures

46

Item 6. Exhibits

46

 

2



Table of Contents

 

Part I

FINANCIAL INFORMATION

 

Item 1.    Financial Statements.

 

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(in thousands, except per share data)

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(Unaudited)

 

Revenues

 

$

688,544

 

$

742,180

 

$

2,010,011

 

$

2,191,927

 

Costs, expenses and other operating

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

540,192

 

647,096

 

1,668,766

 

1,955,547

 

Depreciation, depletion and amortization

 

103,965

 

105,155

 

306,211

 

312,042

 

Amortization of acquired sales contracts, net

 

(1,994

)

(3,013

)

(7,028

)

(9,948

)

Change in fair value of coal derivatives and coal trading activities, net

 

(3,559

)

(3,733

)

(1,128

)

(5,811

)

Asset impairment and mine closure costs

 

2,120,292

 

5,060

 

2,139,438

 

6,572

 

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

––

 

149,314

 

––

 

Selling, general and administrative expenses

 

25,731

 

28,136

 

72,604

 

87,203

 

Other operating (income) expense, net

 

(8,625

)

(1,221

)

7,864

 

(9,451

)

 

 

2,925,316

 

777,480

 

4,336,041

 

2,336,154

 

 

 

 

 

 

 

 

 

 

 

Loss from operations

 

(2,236,772

)

(35,300

)

(2,326,030

)

(144,227

)

Interest expense, net

 

 

 

 

 

 

 

 

 

Interest expense

 

(99,759

)

(98,217

)

(298,585

)

(292,648

)

Interest and investment income

 

672

 

1,949

 

4,007

 

5,828

 

 

 

(99,087

)

(96,268

)

(294,578

)

(286,820

)

Nonoperating expense

 

 

 

 

 

 

 

 

 

Expenses related to debt restructuring

 

(7,482

)

 

(11,498

)

 

 

 

 

 

 

 

 

 

 

 

Loss before income taxes

 

(2,343,341

)

(131,568

)

(2,632,106

)

(431,047

)

Benefit from income taxes

 

(343,865

)

(34,350

)

(351,332

)

(112,830

)

Net loss

 

$

(1,999,476

)

$

(97,218

)

$

(2,280,774

)

$

(318,217

)

 

 

 

 

 

 

 

 

 

 

Net loss per common share

 

 

 

 

 

 

 

 

 

Basic and diluted LPS - Net loss

 

$

(93.91

)

$

(4.58

)

$

(107.16

)

$

(15.00

)

 

 

 

 

 

 

 

 

 

 

Basic and diluted weighted average shares outstanding

 

21,292

 

21,224

 

21,283

 

21,221

 

 

 

 

 

 

 

 

 

 

 

Dividends declared per common share

 

$

 

$

 

$

 

$

0.10

 

 

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

 

3



Table of Contents

 

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (Loss)

(in thousands)

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(Unaudited)

 

Net loss

 

$

(1,999,476

)

$

(97,218

)

$

(2,280,774

)

$

(318,217

)

 

 

 

 

 

 

 

 

 

 

Derivative instruments

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

(2,527

)

520

 

(681

)

1,298

 

Income tax benefit (provision)

 

910

 

(187

)

246

 

(467

)

 

 

(1,617

)

333

 

(435

)

831

 

Pension, postretirement and other post-employment benefits

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

1,182

 

(1,210

)

4,950

 

(5,326

)

Income tax benefit (provision)

 

(425

)

435

 

(1,782

)

1,917

 

 

 

757

 

(775

)

3,168

 

(3,409

)

Available-for-sale securities

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

(362

)

(2,401

)

(3

)

(5,637

)

Income tax benefit (provision)

 

128

 

864

 

(4

)

2,029

 

 

 

(234

)

(1,537

)

(7

)

(3,608

)

 

 

 

 

 

 

 

 

 

 

Total other comprehensive income (loss)

 

(1,094

)

(1,979

)

2,726

 

(6,186

)

Total comprehensive loss

 

$

(2,000,570

)

$

(99,197

)

$

(2,278,048

)

$

(324,403

)

 

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

 

4



Table of Contents

 

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(in thousands, except per share data)

 

 

 

September 30,

 

December 31,

 

 

 

2015

 

2014

 

 

 

(Unaudited)

 

Assets

 

 

 

 

 

Current assets

 

 

 

 

 

Cash and cash equivalents

 

$

494,788

 

$

734,231

 

Short term investments

 

199,731

 

248,954

 

Restricted cash

 

50,409

 

5,678

 

Trade accounts receivable

 

217,667

 

211,506

 

Other receivables

 

21,742

 

20,511

 

Inventories

 

239,035

 

190,253

 

Prepaid royalties

 

10,352

 

11,118

 

Deferred income taxes

 

20,454

 

52,728

 

Coal derivative assets

 

13,743

 

13,257

 

Other current assets

 

51,398

 

54,515

 

Total current assets

 

1,319,319

 

1,542,751

 

Property, plant and equipment, net

 

4,173,038

 

6,453,458

 

Other assets

 

 

 

 

 

Prepaid royalties

 

29,867

 

66,806

 

Equity investments

 

206,347

 

235,842

 

Other noncurrent assets

 

119,426

 

130,866

 

Total other assets

 

355,640

 

433,514

 

Total assets

 

$

5,847,997

 

$

8,429,723

 

Liabilities and Stockholders’ Deficit

 

 

 

 

 

Current liabilities

 

 

 

 

 

Accounts payable

 

$

152,229

 

$

180,113

 

Accrued expenses and other current liabilities

 

310,747

 

302,396

 

Current maturities of debt

 

32,237

 

36,885

 

Total current liabilities

 

495,213

 

519,394

 

Long-term debt

 

5,108,492

 

5,123,485

 

Asset retirement obligations

 

414,194

 

398,896

 

Accrued pension benefits

 

12,061

 

16,260

 

Accrued postretirement benefits other than pension

 

33,966

 

32,668

 

Accrued workers’ compensation

 

95,905

 

94,291

 

Deferred income taxes

 

44,806

 

422,809

 

Other noncurrent liabilities

 

248,800

 

153,766

 

Total liabilities

 

6,453,437

 

6,761,569

 

Stockholders’ deficit

 

 

 

 

 

Common stock, $0.01 par value, authorized 26,000 shares, issued 21,443 shares and 21,379 shares at September 30, 2015 and December 31, 2014, respectively

 

2,145

 

2,141

 

Paid-in capital

 

3,052,910

 

3,048,460

 

Treasury stock, at cost, 152 shares at September 30, 2015 and December 31, 2014

 

(53,863

)

(53,863

)

Accumulated deficit

 

(3,612,599

)

(1,331,825

)

Accumulated other comprehensive income

 

5,967

 

3,241

 

Total stockholders’ deficit

 

(605,440

)

1,668,154

 

Total liabilities and stockholders’ deficit

 

$

5,847,997

 

$

8,429,723

 

 

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

 

5



Table of Contents

 

Arch Coal, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(in thousands)

 

 

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

 

 

(Unaudited)

 

Operating activities

 

 

 

 

 

Net loss

 

$

(2,280,774

)

$

(318,217

)

Adjustments to reconcile net loss to cash used in operating activities:

 

 

 

 

 

Depreciation, depletion and amortization

 

306,211

 

312,042

 

Amortization of acquired sales contracts, net

 

(7,028

)

(9,948

)

Amortization relating to financing activities

 

18,960

 

12,349

 

Prepaid royalties expensed

 

6,661

 

5,645

 

Employee stock-based compensation expense

 

4,459

 

7,689

 

Asset impairment and non-cash mine closure costs

 

2,136,610

 

1,512

 

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

 

Expenses related to debt restructuring

 

11,498

 

 

Amortization of premiums on debt securities held

 

2,143

 

 

Gains on disposals and divestitures, net

 

(1,191

)

(21,965

)

Deferred income taxes

 

(347,180

)

(112,998

)

Changes in:

 

 

 

 

 

Receivables

 

(3,165

)

(6,779

)

Inventories

 

(48,848

)

22,589

 

Accounts payable, accrued expenses and other current liabilities

 

(19,338

)

73,324

 

Income taxes, net

 

(4,303

)

(514

)

Other

 

(3,711

)

37,261

 

Cash provided by (used in) operating activities

 

(79,682

)

1,990

 

Investing activities

 

 

 

 

 

Capital expenditures

 

(109,250

)

(118,701

)

Additions to prepaid royalties

 

(5,808

)

(3,604

)

Proceeds from disposals and divestitures

 

1,020

 

50,971

 

Purchases of marketable securities

 

(203,094

)

(181,546

)

Proceeds from sale or maturity of marketable securities and other investments

 

248,362

 

178,293

 

Investments in and advances to affiliates

 

(7,944

)

(13,393

)

Cash used in investing activities

 

(76,714

)

(87,980

)

Financing activities

 

 

 

 

 

Payments on term loan

 

(14,625

)

(14,625

)

Net payments on other debt

 

(12,192

)

(10,187

)

Expenses related to debt restructuring

 

(11,498

)

 

Dividends paid

 

 

(2,123

)

Debt financing costs

 

 

(2,219

)

Deposits of restricted cash

 

(44,732

)

(6

)

Other

 

 

(15

)

Cash used in financing activities

 

(83,047

)

(29,175

)

Decrease in cash and cash equivalents

 

(239,443

)

(115,165

)

Cash and cash equivalents, beginning of period

 

734,231

 

911,099

 

Cash and cash equivalents, end of period

 

$

494,788

 

$

795,934

 

 

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

 

6



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. and its subsidiaries (the “Company”). The Company’s primary business is the production of thermal and metallurgical coal from surface and underground mines located throughout the United States, for sale to utility, industrial and steel producers both in the United States and around the world. The Company currently operates mining complexes in West Virginia, Kentucky, Maryland, Virginia, Illinois, Wyoming and Colorado.  All subsidiaries are wholly-owned. Intercompany transactions and accounts have been eliminated in consolidation.

 

On August 4, 2015 we effected a 1-for-10 reverse stock split of our common stock.  Each stockholder’s percentage ownership and proportional voting power remained unchanged as a result of the reverse stock split.  All applicable share data, per share amounts and related information in the Condensed Consolidated Financial Statements and notes thereto have been adjusted retroactively to give effect to the 1-for-10 reverse stock split.

 

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 nine months ended September 30, 2015 are not necessarily indicative of results to be expected for the year ending December 31, 2015. 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, 2014 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

 

The Company incurred a net loss for the years ended 2014, 2013 and 2012 and will report a net loss in the current year as well.  Additionally, in 2014 and 2015, the Company has been unable to generate sufficient cash to cover interest expense and capital expenditures.   The Company launched subordinated debt exchange offers in July 2015 that, if successful, would have substantially improved the Company’s leverage profile.  The exchange offers were terminated on October 27, 2015 as a result of various factors, including the actions of the Company’s term lenders in directing the term loan agent not to execute the required documents as well as highly challenging market conditions.

 

With the extremely challenging market conditions currently facing the industry, the Company will require a significant restructuring of its balance sheet to continue to operate as a going concern over the long term.  The Company is currently in active dialogue with various creditors with respect to restructuring of the Company’s balance sheet.  The Company’s mining operations and customer shipments are continuing as normal and the Company has no near-term maturities.

 

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern.  The Company’s ability to continue as a going concern is contingent upon the Company’s ability to restructure its balance sheet with the various creditor parties; there can be no assurance that these efforts will results in any such agreement.  The accompanying consolidated financial statements do not include any adjustments related to the recoverability and classification of assets or the amounts and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

2.  Accounting Policies

 

In April 2015, the Financial Accounting Standards Board (“FASB”) issued the Accounting Standards Update No. 2015-03 (“ASU 2015-03”), Simplifying the Presentation of Debt Issuance Costs. ASU 2015-03 requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the carrying amount of that liability,

 

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consistent with debt discounts. Amendments in this update are effective retrospectively for fiscal years and interim periods within those years, beginning after December 15, 2015, with early adoption permitted. Upon adoption of this guidance, the current financial statement classification of debt issuance costs will change from total assets to long-term debt on our Condensed Consolidated Balance Sheet.

 

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, 2014

 

$

2,550

 

$

2,860

 

$

(2,169

)

$

3,241

 

Unrealized gains (losses)

 

3,919

 

 

(3,401

)

518

 

Amounts reclassified from AOCI

 

(4,354

)

3,168

 

3,394

 

2,208

 

Balance at September 30, 2015

 

$

2,115

 

$

6,028

 

$

(2,176

)

$

5,967

 

 

The following amounts were reclassified out of AOCI:

 

 

 

Amounts Reclassified from AOCI

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

Line Item in the
Condensed Consolidated

 

Details About AOCI Components

 

2015

 

2014

 

2015

 

2014

 

Statement of Operations

 

 

 

(In thousands)

 

 

 

Derivative instruments

 

$

3,598

 

$

892

 

$

6,806

 

$

1,346

 

Revenues

 

 

 

(1,295

)

(321

)

(2,452

)

(485

)

Benefit from income taxes

 

 

 

$

2,303

 

$

571

 

$

4,354

 

$

861

 

Net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

Pension, postretirement and other post-employment benefits

 

 

 

 

 

 

 

 

 

 

 

Amortization of prior service credits (1)

 

$

2,083

 

$

1,759

 

$

6,250

 

$

6,976

 

 

 

Amortization of actuarial gains (losses), net (1)

 

(3,266

)

(550

)

(11,200

)

(1,650

)

 

 

 

 

(1,183

)

1,209

 

(4,950

)

5,326

 

 

 

 

 

426

 

(435

)

1,782

 

(1,917

)

Benefit from income taxes

 

 

 

$

(757

)

$

774

 

$

(3,168

)

$

3,409

 

Net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

Available-for-sale securities

 

$

(1,081

)

$

(145

)

$

(5,308

)

$

(1,824

)

Interest and investment income

 

 

 

358

 

53

 

1,914

 

657

 

Benefit from income taxes

 

 

 

$

(723

)

$

(92

)

$

(3,394

)

$

(1,167

)

Net of tax

 

 


1 Production-related benefits and workers’ compensation costs are included in inventoriable production costs.

 

8



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4.  Divestitures

 

During the first quarter of 2014, the Company entered into agreements to sell an operating thermal coal complex and an idled thermal coal mine in Kentucky and the Company’s ADDCAR subsidiary, which manufactures a patented highwall mining system.  The sales closed in the first quarter of 2014 for total consideration of $45.3 million.  The Company received $26.3 million in cash in the first quarter of 2014, and the remainder was paid in the second and fourth quarters of 2014.  The Company recognized a net pre-tax gain of $14.3 million from these divestitures, reflected in “other operating (income) expense, net” in the Condensed Consolidated Statements of Operations.

 

5.  Asset Impairment and Mine Closure Costs

 

The following describes the costs reflected on the line “Asset impairment and mine closure costs” in the Condensed Consolidated Statements of Operations.

 

As a result of the continued deterioration in thermal and metallurgical coal markets and projections for a muted pricing recovery, certain of the Company’s mine complexes have incurred and are expected to continue to incur operating losses. The company has determined that the further weakening of the pricing environment in the third quarter and the projected operating losses represent indicators of impairment with respect to certain of its long-lived assets or assets groups. Using current pricing expectations which reflect marketplace participant assumptions, life of mine cash flows were used to determine if the undiscounted cash flows exceed the current asset values for certain operating complexes in the Company’s Appalachia segment.  For two operating complexes, the undiscounted cash flows did not exceed the carrying value of the long-lived assets.  Discounted cash flows were utilized to reduce the carrying value of those assets to fair value.  The discount rate used reflects the current financial difficulties present in the commodities sector in general and coal mining specifically; the perceived risk of financing coal mining in light of industry defaults; and the lack of an active market for buying or selling coal mining assets.  Additionally, the Company determined that the current market conditions represent an indicator of impairment for certain undeveloped coal properties that were acquired in times of significantly higher coal prices. Current prices and the significant capital outlay that would be required to develop these reserves indicate that the carrying value is not recoverable.  As a result the Company recorded a $2.1 billion asset impairment charge in the current quarter of which $1.7 billion was recorded to our Appalachian segment, and the remaining $0.4 billion to other operating segments. The remaining fair value of the impaired assets is $470.6 million.

 

During the second quarter of 2015, the Company recorded $19.1 million to “Asset impairment and mine closure costs” in the Condensed Consolidated Statements of Operations.  An impairment charge of $12.2 million relates to the portion of an advance royalty balance on a reserve base mined at the Company’s Mountain Laurel, Spruce and Briar Branch operations that will not be recouped based on latest estimates of sales volume and pricing through the March 2017 recoupment period.  Additionally, the company recorded a $5.6 million impairment charge related to the closure of a higher-cost mining complex serving the metallurgical coal markets.

 

In response to weak metallurgical coal markets, the Company idled a higher-cost mining complex in the third quarter of 2014 in order to concentrate on metallurgical coal production from its lowest-cost and highest-margin operations.  Closure charges of $5.1 million were recognized during the third quarter of 2014 relating to the idling.

 

6.  Losses from disposed operations resulting from Patriot Coal bankruptcy

 

On December 31, 2005, Arch entered into a purchase and sale agreement with Magnum to sell certain operations. On July 23, 2008, Patriot acquired Magnum. On May 12, 2015, Patriot and certain of its wholly owned subsidiaries (“Debtors”), including Magnum, filed voluntary petitions for reorganization under Chapter 11 of the U.S. Code in the U.S. Bankruptcy Court for the Eastern District of Virginia. Subsequently, on October 28, 2015, Patriot’s Plan of Reorganization was approved, including an authorization to reject their collective bargaining agreements and modify certain union-related retiree benefits. As a result of the Plan of Reorganization, the Company became statutorily responsible for retiree medical benefits pursuant to Section 9711 of the Coal Industry Retiree Health Benefit Act of 1992 for certain retirees of Magnum who retired prior to October 1, 1994.

 

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In addition, the Company has provided surety bonds to Patriot related to permits that were sold to an affiliate of Virginia Conservation Legacy Fund, Inc. (“VCLF”). Should VCLF not perform required reclamation, the Company would incur losses under the bonds and related indemnity agreements. During the third quarter of 2015, the Company recognized $149.3 million in losses related to the previously disposed operations as a result of the Patriot Coal bankruptcy.

 

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7.  Inventories

 

Inventories consist of the following:

 

 

 

September 30,

 

December 31,

 

 

 

2015

 

2014

 

 

 

(In thousands)

 

Coal

 

$

119,785

 

$

71,901

 

Repair parts and supplies

 

119,250

 

118,352

 

 

 

$

239,035

 

$

190,253

 

 

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $6.7 million at September 30, 2015 and $6.6 million at December 31, 2014.

 

8.   Investments in Available-for-Sale Securities

 

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

 

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

 

 

 

September 30, 2015

 

 

 

 

 

 

 

 

 

 

 

Balance Sheet

 

 

 

 

 

Accumulated

 

 

 

Classification

 

 

 

 

 

Gross Unrealized

 

Fair

 

Short-Term

 

Other

 

 

 

Cost Basis

 

Gains

 

Losses

 

Value

 

Investments

 

Assets

 

 

 

(In thousands)

 

Available-for-sale:

 

 

 

 

 

 

 

 

 

 

 

 

 

Corporate notes and bonds

 

$

199,440

 

$

359

 

$

(68

)

$

199,731

 

$

199,731

 

$

 

Equity securities

 

3,937

 

549

 

(2,871

)

1,615

 

 

1,615

 

Total Investments

 

$

203,377

 

$

908

 

$

(2,939

)

$

201,346

 

$

199,731

 

$

1,615

 

 

 

 

December 31, 2014

 

 

 

 

 

 

 

 

 

 

 

Balance Sheet

 

 

 

 

 

Gross

 

Gross

 

 

 

Classification

 

 

 

 

 

Unrealized

 

Unrealized

 

Fair

 

Short-Term

 

Other

 

 

 

Cost Basis

 

Gains

 

Losses

 

Value

 

Investments

 

Assets

 

 

 

(In thousands)

 

Available-for-sale:

 

 

 

 

 

 

 

 

 

 

 

 

 

Corporate notes and bonds

 

$

253,590

 

$

 

$

(4,636

)

$

248,954

 

$

248,954

 

$

 

Equity securities

 

3,910

 

4,125

 

(2,890

)

5,145

 

 

5,145

 

Total Investments

 

$

257,500

 

$

4,125

 

$

(7,526

)

$

254,099

 

$

248,954

 

$

5,145

 

 

The aggregate fair value of investments with unrealized losses that were owned for less than a year was $56.1 million and $163.0 million at September 30, 2015 and December 31, 2014, respectively. The aggregate fair value of investments with unrealized losses that were owned for over a year, and were also in a continuous unrealized loss position during that time, was $0.2 million and $86.1 million at September 30, 2015 and December 31, 2014, respectively.  The unrealized losses in the Company’s portfolio are the result of normal market fluctuations.  The Company does not currently intend to sell these investments before recovery of their amortized cost base.

 

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The debt securities outstanding at September 30, 2015 have maturity dates ranging from the fourth quarter of 2015 through the first quarter of 2017.  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.

 

9.   Derivatives

 

Diesel fuel price risk management

 

The Company is exposed to price risk with respect to diesel fuel purchased for use in its operations. The Company anticipates purchasing approximately 55 to 65 million gallons per year of diesel fuel for use in its operations during 2015 and 2016.  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 September 30, 2015, the Company had protected the price of approximately 100% of its expected purchases for the remainder of the year with out-of-the-money call options with an average strike price of $3.13 per gallon.  Additionally, the Company has protected approximately 67%  of our expected 2016 purchases with out-of-the-money call options with an average strike price of $2.26 per gallon.  At September 30, 2015, the Company had outstanding heating oil call options for approximately 54 million gallons for the purpose of managing the price risk associated with future diesel purchases.  These positions are not accounted for as hedges.

 

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 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 September 30, 2015, the Company held derivatives for risk management purposes that are expected to settle in the following years:

 

(Tons in thousands)

 

2015

 

2016

 

Total

 

Coal sales

 

1,205

 

280

 

1,485

 

Coal purchases

 

696

 

240

 

936

 

 

The Company has also entered into a nominal quantity of natural gas put options to protect the Company from decreases in natural gas prices, which could impact coal demand.  These options are not accounted for 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 $1.4 million of gains during the remainder of 2015 and $5.3 million of gains in 2016.

 

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.

 

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Table of Contents

 

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:

 

 

 

September 30, 2015

 

 

 

December 31, 2014

 

 

 

Fair Value of Derivatives

 

Asset

 

Liability

 

 

 

Asset

 

Liability

 

 

 

(In thousands)

 

Derivative

 

Derivative

 

 

 

Derivative

 

Derivative

 

 

 

Derivatives Designated as Hedging Instruments

 

 

 

 

 

 

 

 

 

 

 

 

 

Coal

 

$

1,608

 

$

 

 

 

$

6,535

 

$

(2,492

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives Not Designated as Hedging Instruments

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating oil — diesel purchases

 

600

 

 

 

 

300

 

 

 

 

Coal — held for trading purposes

 

121,312

 

(114,636

)

 

 

96,898

 

(93,272

)

 

 

Coal — risk management

 

9,965

 

(6,257

)

 

 

8,510

 

(3,688

)

 

 

Natural gas

 

1,215

 

 

 

 

 

 

 

 

Foreign currency

 

285

 

 

 

 

 

 

 

 

 

 

Total

 

133,377

 

(120,893

)

 

 

105,708

 

(96,960

)

 

 

Total derivatives

 

134,985

 

(120,893

)

 

 

112,243

 

(99,452

)

 

 

Effect of counterparty netting

 

(120,357

)

120,357

 

 

 

(98,686

)

98,686

 

 

 

Net derivatives as classified in the balance sheets

 

$

14,628

 

$

(536

)

$

14,092

 

$

13,557

 

$

(766

)

$

12,791

 

 

 

 

 

 

September 30,
2015

 

December 31, 2014

 

Net derivatives as reflected on the balance sheets (in thousands)

 

 

 

 

 

 

 

Heating oil and foreign currency

 

Other current assets

 

$

885

 

$

300

 

Coal and natural gas

 

Coal derivative assets

 

13,743

 

13,257

 

 

 

Accrued expenses and other current liabilities

 

(536

)

(766

)

 

 

 

 

$

14,092

 

$

12,791

 

 

The Company had a current asset for the right to reclaim cash collateral of $2.9 million at September 30, 2015 and the obligation to return cash collateral of $2.4 million at December 31, 2014, respectively. These amounts are not included with the derivatives presented in the table above and are included in “other current assets” and “accrued expenses and other current liabilities”, respectively, in the accompanying Condensed Consolidated Balance Sheets.

 

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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 September 30,

 

 

 

Gain (Loss) Recognized in
Other Comprehensive
Income(Effective Portion)

 

Gains (Losses) Reclassified
from Other Comprehensive
Income into Income
(Effective Portion)

 

 

 

2015

 

2014

 

2015

 

2014

 

Coal sales

(1)

$

3,636

 

$

3,449

 

$

6,683

 

$

1,639

 

Coal purchases

(2)

(2,561

)

(2,041

)

(3,084

)

(747

)

Totals

 

$

1,075

 

$

1,408

 

$

3,599

 

$

892

 

 

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 September 30, 2015 and 2014.

 

Derivatives Not Designated as Hedging Instruments (in thousands)

Three Months Ended September 30,

 

 

 

Gain (Loss) Recognized

 

 

 

2015

 

2014

 

Coal — unrealized

(3)

$

(809

)

$

1,610

 

Coal — realized

(4)

$

511

 

$

502

 

Natural gas — unrealized

(3)

$

(16

)

$

238

 

Heating oil — diesel purchases

(4)

$

(5,525

)

$

(3,746

)

Heating oil — fuel surcharges

(4)

$

 

$

(104

)

Foreign currency

(4)

$

(602

)

$

 

 


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)

Nine Months Ended September 30,

 

 

 

Gain (Loss) Recognized in
Other Comprehensive
Income(Effective Portion)

 

Gains (Losses) Reclassified
from Other Comprehensive
Income into Income
(Effective Portion)

 

 

 

2015

 

2014

 

2015

 

2014

 

Coal sales

(1)

12,738

 

$

4,806

 

$

12,555

 

$

2,568

 

Coal purchases

(2)

(6,612

)

(2,162

)

(5,748

)

(1,222

)

Totals

 

$

6,126

 

$

2,644

 

$

6,807

 

$

1,346

 

 

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 nine month periods ended September 30, 2015 and 2014.

 

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Table of Contents

 

Derivatives Not Designated as Hedging Instruments (in thousands)

Nine Months Ended September 30,

 

 

 

Gain (Loss) Recognized

 

 

 

2015

 

2014

 

Coal — unrealized

(3)

$

(2,095

)

$

455

 

Coal — realized

(4)

$

2,428

 

$

4,699

 

Natural gas — unrealized

(3)

$

(78

)

$

(21

)

Heating oil — diesel purchases

(4)

$

(7,262

)

$

(6,709

)

Heating oil — fuel surcharges

(4)

$

 

$

(405

)

Foreign currency

(4)

$

(602

)

$

 

 


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 September 30, 2015, gains on derivative contracts designated as hedge instruments in cash flow hedges of approximately $0.9 million are expected to be reclassified from other comprehensive income into earnings during the next twelve months.

 

Related to its trading portfolio, the Company recognized net unrealized and realized gains of $4.4 million and $1.9 million during the three months ended September 30, 2015 and 2014, respectively; and net unrealized and realized gains of $3.3 million and $5.4 million during the nine months ended September 30, 2015 and 2014.  Gains and losses from trading activities are included in the caption “Change in fair value of coal derivatives and coal trading activities, net” in the accompanying Condensed Consolidated Statements of Operations, and are not included in the previous tables reflecting the effects of derivatives on measures of financial performance.

 

10.   Accrued Expenses and Other Current Liabilities

 

Accrued expenses and other current liabilities consist of the following:

 

 

 

September 30,

 

December 31,

 

 

 

2015

 

2014

 

 

 

(In thousands)

 

Payroll and employee benefits

 

$

52,305

 

$

73,362

 

Taxes other than income taxes

 

111,208

 

114,598

 

Interest

 

77,423

 

30,384

 

Acquired sales contracts

 

4,946

 

12,453

 

Workers’ compensation

 

17,635

 

16,714

 

Asset retirement obligations

 

19,199

 

19,222

 

Other

 

28,031

 

35,663

 

 

 

$

310,747

 

$

302,396

 

 

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11.  Debt and Financing Arrangements

 

 

 

September 30,

 

December 31,

 

 

 

2015

 

2014

 

 

 

(In thousands)

 

Term loan due 2018 ($1.9 billion face value)

 

$

1,879,261

 

$

1,890,846

 

7.00% senior notes due 2019 at par

 

1,000,000

 

1,000,000

 

9.875% senior notes due 2019 ($375.0 million face value)

 

365,050

 

363,493

 

8.00% senior secured notes due 2019 at par

 

350,000

 

350,000

 

7.25% senior notes due 2020 at par

 

500,000

 

500,000

 

7.25% senior notes due 2021 at par

 

1,000,000

 

1,000,000

 

Other

 

46,418

 

56,031

 

 

 

5,140,729

 

5,160,370

 

Less current maturities of debt

 

32,237

 

36,885

 

Long-term debt

 

$

5,108,492

 

$

5,123,485

 

 

As of September 30, 2015, availability under our revolver was subject to limits on secured debt in our indentures.  At September 30, 2015, the limit under our most restrictive indenture did not provide meaningful availability under the revolver and, as a result, on November 6, 2015 we delivered an irrevocable 5 day notice to the administrative agent to voluntarily terminate all commitments thereunder, which will terminate on November 11, 2015.  We had no borrowings outstanding under our revolving credit facility at September 30, 2015 and had not been using it as a source of liquidity in the recent past.  At September 30, 2015, we had utilized $185.2 million of our $200.0 million receivables securitization facility for letters of credit.  The credit agreement related to the securitization facility expires on December 8, 2017, unless the Company’s minimum liquidity, including liquid assets, falls below $550 million.  If liquidity falls below $550 million, the expiration date of the securitization facility becomes the earlier of December 8, 2017 or nine months from the date that liquidity falls below the minimum.

 

12.    Income Taxes

 

During the first nine months of 2015, the Company determined it was more likely than not that the federal and state net operating losses it expects to generate in 2015 will not be realized based on projections of future taxable income.  Accordingly, the estimated annual effective rate for the year ended December 31, 2015 includes the impact of recording a valuation allowance against these attributes.  During the nine months ended September 30, 2015, the Company realized a net tax benefit of $351.3 million, which included a $794.0 million tax benefit associated with the asset impairment charges partially offset by a valuation allowance of $426.4 million for federal net operating losses and tax credits and $19.3 million for the state net operating losses.

 

During the first nine months of 2014, the Company increased its valuation allowance for the portion of the federal and state net operating losses it expected to generate in 2014.  The Company increased its valuation allowance by $51.7 million for the federal net operating losses and $6.3 million for the state net operating losses.

 

13.  Fair Value Measurements

 

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

 

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

 

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·      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 and commodity contracts (coal and heating oil) with fair values derived from quoted prices in over-the-counter markets or from prices received from direct broker quotes.

 

·      Level 3 is defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. These include the Company’s commodity option contracts (coal, natural gas and heating oil) valued using modeling techniques, such as Black-Scholes, that require the use of inputs, particularly volatility, that are rarely observable. Changes in the unobservable inputs would not have a significant impact on the reported Level 3 fair values at September 30, 2015.

 

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:

 

 

 

September 30, 2015

 

 

 

Total

 

Level 1

 

Level 2

 

Level 3

 

 

 

(In thousands)

 

Assets:

 

 

 

 

 

 

 

 

 

Investments in marketable securities

 

$

201,346

 

$

1,615

 

$

199,731

 

$

 

Derivatives

 

14,628

 

8,322

 

890

 

5,416

 

Total assets

 

$

215,974

 

$

9,937

 

$

200,621

 

$

5,416

 

Liabilities:

 

 

 

 

 

 

 

 

 

Derivatives

 

$

536

 

$

 

$

536

 

$

 

 

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
September 30, 2015

 

Nine Months Ended
September 30, 2015

 

 

 

(In thousands)

 

Balance, beginning of period

 

$

7,840

 

$

3,040

 

Realized and unrealized losses recognized in earnings, net

 

(4,200

)

(6,028

)

Realized and unrealized gains recognized in other comprehensive income, net

 

 

(1,341

)

Purchases

 

2,334

 

11,959

 

Issuances

 

(558

)

(2,214

)

Ending balance

 

$

5,416

 

$

5,416

 

 

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Table of Contents

 

Net unrealized losses of $3.9 million and net unrealized losses of $5.1 million were recognized during the three and nine months ended September 30, 2015, respectively, related to level 3 financial instruments held on September 30, 2015.

 

Fair Value of Long-Term Debt

 

At September 30, 2015 and December 31, 2014, the fair value of the Company’s debt, including amounts classified as current, was $1.4 billion and $2.7 billion, respectively. Fair values are based upon observed prices in an active market, when available, or from valuation models using market information, which fall into Level 2 in the fair value hierarchy.

 

14.   Loss Per Common Share

 

The effect of options, restricted stock and restricted stock units that were excluded from the calculation of diluted weighted average shares outstanding because the exercise price or grant price of the securities exceeded the average market price of the Company’s common stock were:  1.0 million shares of common stock for both the three and nine months ended September 30, 2015, respectively; and 1.0 million shares of common stock for both the three and nine months ended September 30, 2014.  The weighted average share impacts of options, restricted stock and restricted stock units that were excluded from the calculation of weighted average shares due to the Company’s incurring a net loss for the three and nine months ended September 30, 2015 were 0.1 million shares; and 0.2 million shares for the both the three and nine months ended September 30, 2014, respectively.

 

15.  Employee Benefit Plans

 

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

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

Service cost

 

$

2

 

$

4,910

 

$

7

 

$

16,311

 

Interest cost

 

3,688

 

4,278

 

10,953

 

12,834

 

Expected return on plan assets

 

(5,044

)

(5,929

)

(15,275

)

(17,786

)

Curtailments

 

526

 

1,504

 

526

 

1,504

 

Amortization of prior service costs (credits)

 

 

(51

)

 

(158

)

Amortization of other actuarial losses

 

1,395

 

741

 

6,638

 

2,221

 

Net benefit cost

 

$

567

 

$

5,453

 

$

2,849

 

$

14,926

 

 

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

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

Service cost

 

$

216

 

$

383

 

$

649

 

$

1,267

 

Interest cost

 

321

 

460

 

964

 

1,381

 

Amortization of prior service credits

 

(2,084

)

(2,500

)

(6,251

)

(7,502

)

Amortization of other actuarial losses (gains)

 

(527

)

(191

)

(1,582

)

(571

)

Net benefit credit

 

$

(2,074

)

$

(1,848

)

$

(6,220

)

$

(5,425

)

 

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 September 30, 2015 and December 31, 2014, the Company had accrued $4.1 million and $22.3 million, respectively, for all legal matters, including $4.1 million and $10.1 million, respectively, 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.

 

17.  Segment Information

 

The Company’s reportable business segments are based on the major coal producing basins in which the Company operates and may include a number of mine complexes. The Company manages its coal sales by coal basin, not by individual mining complex. Geology, coal transportation routes to customers, regulatory environments and coal quality or type are characteristic to a basin, and, accordingly, market and contract pricing have developed by coal basin. Mining operations are evaluated based on adjusted EBITDA, as well as on other non-financial measures, such as safety and environmental performance. The Company’s reportable segments are the Powder River Basin (PRB) segment, with operations in Wyoming; and the Appalachia (APP) segment, with operations primarily in West Virginia.  The “Other” category combines other operating segments and includes the Company’s coal mining operations in Colorado and Illinois.

 

Operating segment results for the three and nine months ended September 30, 2015 and 2014 are presented below. The Company uses Adjusted EBITDA to assess the operating segments’ performance and to allocate resources.  The Company’s management believes that Adjusted EBITDA presents a useful measure of our ability to service existing debt and incur additional debt based on ongoing operations.  Corporate, Other and Eliminations includes the change in fair value of coal derivatives and coal trading activities, net; corporate overhead; land management; other support functions; and the elimination of intercompany transactions.

 

19



Table of Contents

 

 

 

PRB

 

APP

 

Other
Operating
Segments

 

Corporate,
Other and
Eliminations

 

Consolidated

 

 

 

(in thousands)

 

Three Months Ended September 30, 2015

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

390,360

 

$

205,573

 

$

92,611

 

$

 

$

688,544

 

Adjusted EBITDA

 

86,204

 

41,754

 

12,927

 

(6,080

)

134,805

 

Depreciation, depletion and amortization

 

47,321

 

44,098

 

11,193

 

1,353

 

103,965

 

Amortization of acquired sales contracts, net

 

(1,124

)

(870

)

 

 

(1,994

)

Capital expenditures

 

869

 

3,990

 

2,889

 

2,141

 

9,889

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30, 2014

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

389,386

 

$

272,354

 

$

80,440

 

$

0

 

$

742,180

 

Adjusted EBITDA

 

62,771

 

12,327

 

22,412

 

(25,608

)

71,902

 

Depreciation, depletion and amortization

 

43,962

 

48,867

 

10,499

 

1,827

 

105,155

 

Amortization of acquired sales contracts, net

 

(1,200

)

(1,815

)

3

 

(1

)

(3,013

)

Capital expenditures

 

8,174

 

9,039

 

4,678

 

1,064

 

22,955

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30, 2015

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

1,124,046

 

$

653,310

 

$

232,655

 

$

 

$

2,010,011

 

Adjusted EBITDA

 

214,920

 

92,988

 

22,074

 

(68,077

)

261,905

 

Depreciation, depletion and amortization

 

134,393

 

135,028

 

32,082

 

4,708

 

306,211

 

Amortization of acquired sales contracts, net

 

(3,170

)

(3,858

)

 

 

(7,028

)

Total assets

 

1,711,945

 

1,374,436

 

321,449

 

2,440,167

 

5,847,997

 

Capital expenditures

 

22,263

 

15,323

 

7,199

 

64,465

 

109,250

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30, 2014

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

1,106,258

 

$

832,452

 

$

251,239

 

$

1,978

 

$

2,191,927

 

Adjusted EBITDA

 

135,136

 

67,794

 

44,007

 

(82,498

)

164,439

 

Depreciation, depletion and amortization

 

124,243

 

155,087

 

29,601

 

3,111

 

312,042

 

Amortization of acquired sales contracts, net

 

(2,774

)

(7,266

)

93

 

(1

)

(9,948

)

Capital expenditures

 

17,230

 

28,232

 

8,837

 

64,402

 

118,701

 

 

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

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

Adjusted EBITDA

 

$

134,805

 

$

71,902

 

$

261,905

 

$

164,439

 

Depreciation, depletion and amortization

 

(103,965

)

(105,155

)

(306,211

)

(312,042

)

Amortization of acquired sales contracts, net

 

1,994

 

3,013

 

7,028

 

9,948

 

Asset impairment and mine closure costs

 

(2,120,292

)

(5,060

)

(2,139,438

)

(6,572

)

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

(149,314

)

––

 

(149,314

)

––

 

Interest expense, net

 

(99,087

)

(96,268

)

(294,578

)

(286,820

)

Nonoperating expense

 

 

(7,482

)

 

 

(11,498

)

 

Loss before income taxes

 

$

(2,343,341

)

$

(131,568

)

$

(2,632,106

)

$

(431,047

)

 

20



Table of Contents

 

18.  Subsequent Events

 

On July 2, 2015 we launched two private debt exchange offers in an effort to de-lever our balance sheet and improve our liquidity profile.  However, as a result of various factors, including the actions of our term lenders in directing the term loan agent not to execute required documents and current market conditions, on October 27, 2015 we announced termination of the exchange offers.

 

21



Table of Contents

 

19. Supplemental Consolidating Financial Information

 

Pursuant to the indentures governing Arch Coal, Inc.’s senior notes, certain wholly-owned subsidiaries of the Company have fully and unconditionally guaranteed the senior notes on a joint and several basis. The following tables present condensed consolidating financial information for (i) the Company, (ii) the issuer of the senior notes, (iii) the guarantors under the senior notes, and (iv) the entities which are not guarantors under the senior notes (Arch Receivable Company, LLC and the Company’s subsidiaries outside the United States):

 

Condensed Consolidating Statements of Operations

Three Months Ended September 30, 2015

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

688,544

 

$

 

$

 

$

688,544

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

3,211

 

537,471

 

 

(490

)

540,192

 

Depreciation, depletion and amortization

 

896

 

103,069

 

 

 

103,965

 

Amortization of acquired sales contracts, net

 

 

(1,994

)

 

 

(1,994

)

Change in fair value of coal derivatives and coal trading activities, net

 

 

(3,559

)

 

 

(3,559

)

Asset impairment and mine closure costs

 

21,292

 

2,099,000

 

 

 

2,120,292

 

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

––

 

––

 

 

 

149,314

 

Selling, general and administrative expenses

 

18,059

 

6,725

 

1,489

 

(542

)

25,731

 

Other operating (income) expense, net

 

3,503

 

(12,343

)

(817

)

1,032

 

(8,625

)

 

 

196,275

 

2,728,369

 

672

 

 

2,925,316

 

Loss from investment in subsidiaries

 

(2,025,900

)

 

 

2,025,900

 

 

Loss from operations

 

(2,222,175

)

(2,039,825

)

(672

)

2,025,900

 

(2,236,772

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(120,404

)

(6,629

)

(1,199

)

28,473

 

(99,759

)

Interest and investment income

 

6,710

 

20,781

 

1,654

 

(28,473

)

672

 

 

 

(113,694

)

14,152

 

455

 

 

(99,087

)

 

 

 

 

 

 

 

 

 

 

 

 

Expenses related to debt restructuring

 

(7,482

)

 

 

 

(7,482

)

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

(2,343,351

)

(2,025,673

)

(217

)

2,025,900

 

(2,343,341

)

Provision for (benefit from) income taxes

 

(343,875

)

 

10

 

 

(343,865

)

Net income (loss)

 

$

(1,999,476

)

$

(2,025,673

)

$

(227

)

$

2,025,900

 

$

(1,999,476

)

Total comprehensive income (loss)

 

$

(2,000,570

)

$

(2,026,697

)

$

(227

)

$

2,026,924

 

$

(2,000,570

)

 

22



Table of Contents

 

Condensed Consolidating Statements of Operations

Three Months Ended September 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

742,180

 

$

 

$

 

$

742,180

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

2,442

 

645,672

 

 

(1,018

)

647,096

 

Depreciation, depletion and amortization

 

1,175

 

103,971

 

9

 

 

105,155

 

Amortization of acquired sales contracts, net

 

 

(3,013

)

 

 

(3,013

)

Change in fair value of coal derivatives and coal trading activities, net

 

 

(3,733

)

 

 

(3,733

)

Asset impairment and mine closure costs

 

 

5,060

 

 

 

5,060

 

Selling, general and administrative expenses

 

19,542

 

7,427

 

1,679

 

(512

)

28,136

 

Other operating (income) expense, net

 

1,562

 

(2,942

)

(1,371

)

1,530

 

(1,221

)

 

 

24,721

 

752,442

 

317

 

 

777,480

 

Income from investment in subsidiaries

 

2,005

 

 

 

(2,005

)

 

Loss from operations

 

(22,716

)

(10,262

)

(317

)

(2,005

)

(35,300

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(116,742

)

(6,577

)

(1,116

)

26,218

 

(98,217

)

Interest and investment income

 

7,872

 

18,987

 

1,308

 

(26,218

)

1,949

 

 

 

(108,870

)

12,410

 

192

 

 

(96,268

)

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

(131,586

)

2,148

 

(125

)

(2,005

)

(131,568

)

Provision for (benefit from) income taxes

 

(34,368

)

 

(21

)

 

(34,350

)

Net loss

 

$

(97,218

)

$

2,148

 

$

(104

)

$

(2,005

)

$

(97,218

)

Total comprehensive income (loss)

 

$

(99,197

)

$

1,717

 

$

(143

)

$

(1,574

)

$

(99,197

)

 

23



Table of Contents

 

Condensed Consolidating Statements of Operations

Nine Months Ended September 30, 2015

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

2,010,011

 

$

 

$

 

$

2,010,011

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

16,589

 

1,654,348

 

 

(2,171

)

1,668,766

 

Depreciation, depletion and amortization

 

2,969

 

303,240

 

2

 

 

306,211

 

Amortization of acquired sales contracts, net

 

 

(7,028

)

 

 

(7,028

)

Change in fair value of coal derivatives and coal trading activities, net

 

 

(1,128

)

 

 

(1,128

)

Asset impairment and mine closure costs

 

22,517

 

2,116,921

 

 

 

2,139,438

 

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

––

 

––

 

––

 

149,314

 

Selling, general and administrative expenses

 

50,664

 

19,239

 

4,262

 

(1,561

)

72,604

 

Other operating (income) expense, net

 

7,065

 

417

 

(3,350

)

3,732

 

7,864

 

 

 

249,118

 

4,086,009

 

914

 

 

4,336,041

 

Loss from investment in subsidiaries

 

(2,035,313

)

 

 

2,035,313

 

 

Loss from operations

 

(2,284,431

)

(2,075,998

)

(914

)

2,035,313

 

(2,326,030

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(357,690

)

(19,969

)

(3,601

)

82,675

 

(298,585

)

Interest and investment income

 

21,457

 

60,811

 

4,414

 

(82,675

)

4,007

 

 

 

(336,233

)

40,842

 

813

 

 

(294,578

)

 

 

 

 

 

 

 

 

 

 

 

 

Expenses related to debt restructuring

 

(11,498

)

 

 

 

(11,498

)

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

(2,632,162

)

(2,035,156

)

(101

)

2,035,313

 

(2,632,106

)

Provision for (benefit from) income taxes

 

(351,388

)

 

56

 

 

(351,332

)

Net income (loss)

 

$

(2,280,774

)

$

(2,035,156

)

$

(157

)

$

2,035,313

 

$

(2,280,774

)

Total comprehensive income (loss)

 

$

(2,278,048

)

$

(2,033,102

)

$

(157

)

$

2,033,259

 

$

(2,278,048

)

 

24



Table of Contents

 

Condensed Consolidating Statements of Operations

Nine Months Ended September 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

2,191,927

 

$

 

$

 

$

2,191,927

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

9,378

 

1,948,918

 

 

(2,749

)

1,955,547

 

Depreciation, depletion and amortization

 

3,993

 

308,022

 

27

 

 

312,042

 

Amortization of acquired sales contracts, net

 

 

(9,948

)

 

 

(9,948

)

Change in fair value of coal derivatives and coal trading activities, net

 

 

(5,811

)

 

 

(5,811

)

Asset impairment and mine closure costs

 

1,512

 

5,060

 

 

 

6,572

 

Selling, general and administrative expenses

 

61,216

 

22,540

 

4,971

 

(1,524

)

87,203

 

Other operating (income) expense, net

 

1,272

 

(10,869

)

(4,127

)

4,273

 

(9,451

)

 

 

77,371

 

2,257,912

 

871

 

 

2,336,154

 

Loss from investment in subsidiaries

 

(30,839

)

 

 

30,839

 

 

Loss from operations

 

(108,210

)

(65,985

)

(871

)

30,839

 

(144,227

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(346,481

)

(19,466

)

(3,258

)

76,557

 

(292,648

)

Interest and investment income

 

23,598

 

54,979

 

3,808

 

(76,557

)

5,828

 

 

 

(322,883

)

35,513

 

550

 

 

(286,820

)

 

 

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations before income taxes

 

(431,093

)

(30,472

)

(321

)

30,839

 

(431,047

)

Provision for (benefit from) income taxes

 

(112,876

)

 

46

 

 

(112,830

)

Net loss

 

$

(318,217

)

$

(30,472

)

$

(367

)

$

30,839

 

$

(318,217

)

Total comprehensive loss

 

$

(324,403

)

$

(33,062

)

$

(367

)

$

33,429

 

$

(324,403

)

 

25



Table of Contents

 

Condensed Consolidating Balance Sheets

September 30, 2015

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

362,643

 

$

120,484

 

$

11,661

 

$

 

$

494,788

 

Short term investments

 

199,731

 

 

 

 

199,731

 

Restricted cash

 

 

 

50,409

 

 

50,409

 

Receivables

 

14,307

 

12,502

 

216,959

 

(4,359

)

239,409

 

Inventories

 

 

239,035

 

 

 

239,035

 

Other

 

50,449

 

44,565

 

933

 

 

95,947

 

Total current assets

 

627,130

 

416,586

 

279,962

 

(4,359

)

1,319,319

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, plant and equipment, net

 

8,447

 

4,164,189

 

 

402

 

4,173,038

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment in subsidiaries

 

5,421,088

 

 

 

(5,421,088

)

 

Intercompany receivables

 

 

2,225,149

 

 

(2,225,149

)

 

Note receivable from Arch Western

 

675,000

 

 

 

(675,000

)

 

Other

 

99,939

 

254,712

 

989

 

 

355,640

 

Total other assets

 

6,196,027

 

2,479,861

 

989

 

(8,321,237

)

355,640

 

Total assets

 

$

6,831,604

 

$

7,060,636

 

$

280,951

 

$

(8,325,194

)

$

5,847,997

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

 

 

 

 

Accounts payable

 

$

13,566

 

$

138,624

 

$

39

 

$

 

$

152,229

 

Accrued expenses and other current liabilities

 

118,662

 

195,577

 

867

 

(4,359

)

310,747

 

Current maturities of debt

 

21,810

 

10,427

 

 

 

32,237

 

Total current liabilities

 

154,038

 

344,628

 

906

 

(4,359

)

495,213

 

Long-term debt

 

5,074,812

 

33,680

 

 

 

5,108,492

 

Intercompany payables

 

1,971,290

 

 

253,859

 

(2,225,149

)

 

Note payable to Arch Coal

 

 

675,000

 

 

(675,000

)

 

Asset retirement obligations

 

1,037

 

413,157

 

 

 

414,194

 

Accrued pension benefits

 

4,247

 

7,814

 

 

 

12,061

 

Accrued postretirement benefits other than pension

 

4,234

 

29,732

 

 

 

33,966

 

Accrued workers’ compensation

 

10,291

 

85,614

 

 

 

95,905

 

Deferred income taxes

 

44,806

 

 

 

 

44,806

 

Other noncurrent liabilities

 

172,691

 

75,810

 

299

 

 

248,800

 

Total liabilities

 

7,437,446

 

1,665,435

 

255,064

 

(2,904,508

)

6,453,437

 

Stockholders’ equity

 

(605,842

)

5,395,201

 

25,887

 

(5,420,686

)

(605,440

)

Total liabilities and stockholders’ equity

 

$

6,831,604

 

$

7,060,636

 

$

280,951

 

$

(8,325,194

)

$

5,847,997

 

 

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Table of Contents

 

Condensed Consolidating Balance Sheets

December 31, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

572,185

 

$

150,358

 

$

11,688

 

$

 

$

734,231

 

Short term investments

 

248,954

 

 

 

 

248,954

 

Restricted cash

 

 

 

5,678

 

 

5,678

 

Receivables

 

9,656

 

15,933

 

211,043

 

(4,615

)

232,017

 

Inventories

 

 

190,253

 

 

 

190,253

 

Other

 

89,211

 

41,455

 

952

 

 

131,618

 

Total current assets

 

920,006

 

397,999

 

229,361

 

(4,615

)

1,542,751

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, plant and equipment, net

 

10,470

 

6,442,623

 

2

 

363

 

6,453,458

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment in subsidiaries

 

7,464,221

 

 

 

(7,464,221

)

 

Intercompany receivables

 

 

2,021,110

 

 

(2,021,110

)

 

Note receivable from Arch Western

 

675,000

 

 

 

(675,000

)

 

Other

 

131,884

 

300,058

 

1,572

 

 

433,514

 

Total other assets

 

8,271,105

 

2,321,168

 

1,572

 

(10,160,331

)

433,514

 

Total assets

 

$

9,201,581

 

$

9,161,790

 

$

230,935

 

$

(10,164,583

)

$

8,429,723

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

 

 

 

 

Accounts payable

 

$

23,394

 

$

156,664

 

$

55

 

$

 

$

180,113

 

Accrued expenses and other current liabilities

 

85,899

 

220,017

 

1,095

 

(4,615

)

302,396

 

Current maturities of debt

 

27,625

 

9,260

 

 

 

36,885

 

Total current liabilities

 

136,918

 

385,941

 

1,150

 

(4,615

)

519,394

 

Long-term debt

 

5,084,839

 

38,646

 

 

 

5,123,485

 

Intercompany payables

 

1,817,755

 

 

203,355

 

(2,021,110

)

 

Note payable to Arch Coal

 

 

675,000

 

 

(675,000

)

 

Asset retirement obligations

 

981

 

397,915

 

 

 

398,896

 

Accrued pension benefits

 

5,967

 

10,293

 

 

 

16,260

 

Accrued postretirement benefits other than pension

 

4,430

 

28,238

 

 

 

32,668

 

Accrued workers’ compensation

 

9,172

 

85,119

 

 

 

94,291

 

Deferred income taxes

 

422,809

 

 

 

 

422,809

 

Other noncurrent liabilities

 

50,919

 

102,461

 

386

 

 

153,766

 

Total liabilities

 

7,533,790

 

1,723,613

 

204,891

 

(2,700,725

)

6,761,569

 

Stockholders’ equity

 

1,667,791

 

7,438,177

 

26,044

 

(7,463,858

)

1,668,154

 

Total liabilities and stockholders’ equity

 

$

9,201,581

 

$

9,161,790

 

$

230,935

 

$

(10,164,583

)

$

8,429,723

 

 

27



Table of Contents

 

Condensed Consolidating Statements of Cash Flows

Nine Months Ended September 30, 2015

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Cash provided by (used in) operating activities

 

$

(353,386

)

$

279,503

 

$

(5,799

)

$

 

$

(79,682

)

Investing Activities

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

(956

)

(108,294

)

 

 

(109,250

)

Additions to prepaid royalties

 

 

(5,808

)

 

 

(5,808

)

Proceeds from disposals and divestitures

 

 

1,020

 

 

 

1,020

 

Purchases of marketable securities

 

(203,094

)

 

 

 

(203,094

)

Proceeds from sale or maturity of marketable securities and other investments

 

248,362

 

 

 

 

248,362

 

Investments in and advances to affiliates

 

(788

)

(7,156

)

 

 

(7,944

)

Cash used in investing activities

 

43,524

 

(120,238

)

 

 

(76,714

)

Financing Activities

 

 

 

 

 

 

 

 

 

 

 

Payments on term loan

 

(14,625

)

 

 

 

(14,625

)

Net payments on other debt

 

(5,814

)

(6,378

)

 

 

(12,192

)

Expenses related to debt restructuring

 

(11,498

)

 

 

 

(11,498

)

Deposits of restricted cash

 

 

 

(44,732

)

 

(44,732

)

Transactions with affiliates, net

 

132,257

 

(182,761

)

50,504

 

 

 

Cash provided by (used in) financing activities

 

100,320

 

(189,139

)

5,772

 

 

(83,047

)

Decrease in cash and cash equivalents

 

(209,542

)

(29,874

)

(27

)

 

(239,443

)

Cash and cash equivalents, beginning of period

 

572,185

 

150,358

 

11,688

 

 

734,231

 

Cash and cash equivalents, end of period

 

$

362,643

 

$

120,484

 

$

11,661

 

$

 

$

494,788

 

 

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Table of Contents

 

Condensed Consolidating Statements of Cash Flows

Nine Months Ended September 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Cash provided by (used in) operating activities

 

$

(342,497

)

$

360,036

 

$

(15,549

)

$

 

$

1,990

 

Investing Activities

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

(1,195

)

(117,506

)

 

 

(118,701

)

Additions to prepaid royalties

 

 

(3,604

)

 

 

(3,604

)

Proceeds from disposals and divestitures

 

46,634

 

4,337

 

 

 

50,971

 

Purchases of short term investments

 

(181,546

)

 

 

 

(181,546

)

Proceeds from sales of short term investments

 

178,293

 

 

 

 

178,293

 

Investments in and advances to affiliates

 

(2,047

)

(11,346

)

 

 

(13,393

)

Cash provided by (used in) investing activities

 

40,139

 

(128,119

)

 

 

(87,980

)

Financing Activities

 

 

 

 

 

 

 

 

 

 

 

Payments on term loan

 

(14,625

)

 

 

 

(14,625

)

Debt financing costs

 

(2,219

)

 

 

 

(2,219

)

Net payments on other debt

 

(6,814

)

(3,373

)

 

 

(10,187

)

Dividends paid

 

(2,123

)

 

 

 

(2,123

)

Change in restricted cash

 

 

 

(6

)

 

(6

)

Other

 

(15

)

 

 

 

(15

)

Transactions with affiliates, net

 

162,643

 

(178,603

)

15,960

 

 

 

Cash provided by (used in) financing activities

 

136,847

 

(181,976

)

15,954

 

 

(29,175

)

Increase (decrease) in cash and cash equivalents

 

(165,511

)

49,941

 

405

 

 

(115,165

)

Cash and cash equivalents, beginning of period

 

799,333

 

100,418

 

11,348

 

 

911,099

 

Cash and cash equivalents, end of period

 

$

633,822

 

$

150,359

 

$

11,753

 

$

 

$

795,934

 

 

29



Table of Contents

 

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

 

Overview

 

The coal industry remains in a period of distress due to strict governmental regulations, oversupply in the global coal market, increased competition from natural gas, and low coal demand and prices, among other factors.  Many coal companies, including Arch, have been consistently reporting cash burn and losses, and, due to current market conditions, expect to continue to use cash and report losses for the foreseeable future.  Our EBITDA has been insufficient to cover our interest expense and capital expenditures, our debt to EBITDA leverage levels have become unsustainably high, and our debt has traded at a substantial discount to par, rendering us unable to access the capital markets for new capital.  We launched exchange offers in July 2015 that, if successful, would have improved our leverage profile.  However, as a result of various factors, including the actions of our term lenders in directing the term loan agent not to execute required documents as well as highly challenging market conditions, on October 27, 2015 we announced termination of the exchange offers.

 

With these extremely challenging market conditions, we will require a significant restructuring of our balance sheet to continue to operate as a going concern over the long term.  We are currently in active dialogue with various creditors with respect to a restructuring of our balance sheet.  Our mining operations and customer shipments are continuing as normal and we operate efficient, large-scale mines that we believe will remain competitive in most market environments.

 

Our regional results during the third quarter of 2015, when compared to the third quarter of 2014, were supported by improved productivity at our Appalachian longwall operations, lower diesel fuel pricing, modest sales volume improvement in the PRB and Other segments, and other cost control measures.  These improvements were partially offset by continued weakness in domestic thermal markets and deepening weakness in metallurgical coal markets.

 

Pricing and volume for our metallurgical products continues to be pressured by ongoing global oversupply and the relative strength of the U.S. dollar.  Slowing economic growth in China and globally has slowed demand growth, and supply rationalization has been slow to take effect.  The relative strength of the U.S. dollar benefits our foreign competitors in the global metallurgical and thermal markets as much of their input costs are in their local currencies.  We sold 1.6 million tons of metallurgical coal during the third quarter of 2015 compared to 1.7 million tons during the third quarter of 2014, and 4.7 million tons of metallurgical coal during the first three quarters of 2015 compared to 5.0 million tons during the first three quarters of 2014. Overseas thermal markets are uneconomic for substantially all U.S. production at current pricing levels.

 

Domestic thermal coal volumes increased slightly in the PRB and Other segments while continuing to decrease in Appalachia.  Low natural gas pricing and implementation of the Mercury Air Toxics standards, (MATS), continue to be the major drivers of weakness in the domestic thermal markets.  Natural gas pricing during the third quarter of 2015 remained low enough for it to compete economically with coal as an electric generation fuel more widely than in the third quarter of 2014.  Appalachian thermal coal, with its higher cost structure, is particularly vulnerable to competition from low natural gas prices.  Additionally, regional natural gas prices have been lower than the national average in some traditional Appalachian thermal coal markets, particularly the Mid-Atlantic.  Closure of some coal fueled facilities to comply with the MATS regulation further reduces demand compared to the prior year quarter.  Although the closed coal-fueled plants were generally older, smaller, and less utilized than the remaining fleet, the closures do have a negative impact on demand.

 

See further information regarding committed sales in Item 3. Quantitative and Qualitative Disclosures About Market Risk.

 

Regional Performance

 

The following table shows results by operating segment for the three and nine months ended September 30, 2015 and compares them with the information for the three and nine months ended September 30, 2014.  The “Other” category represents

 

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the results of our other bituminous thermal operations: our West Elk mining complex in Colorado and our Viper mining complex in Illinois.

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

Powder River Basin

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

29,469

 

29,266

 

83,484

 

81,860

 

Coal sales per ton sold

 

$

13.07

 

$

13.03

 

$

13.26

 

$

12.86

 

Cost per ton sold

 

$

11.71

 

$

12.42

 

$

12.27

 

$

12.66

 

Operating margin per ton sold

 

$

1.36

 

$

0.61

 

$

0.99

 

$

0.20

 

Adjusted EBITDA (in thousands)

 

$

86,204

 

$

62,771

 

$

214,920

 

$

135,136

 

Appalachia

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

2,993

 

3,619

 

9,113

 

10,895

 

Coal sales per ton sold

 

$

62.24

 

$

68.72

 

$

64.45

 

$

68.60

 

Cost per ton sold

 

$

63.70

 

$

79.87

 

$

69.65

 

$

78.95

 

Operating loss per ton sold

 

$

(1.46

)

$

(11.15

)

$

(5.20

)

$

(10.35

)

Adjusted EBITDA (in thousands)

 

$

41,754

 

$

12,327

 

$

92,988

 

$

67,794

 

Other

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

2,340

 

2,243

 

5,886

 

6,393

 

Coal sales per ton sold

 

$

30.20

 

$

31.81

 

$

31.14

 

$

30.62

 

Cost per ton sold

 

$

24.63

 

$

24.16

 

$

26.81

 

25.26

 

Operating margin per ton sold

 

$

5.57

 

$

7.65

 

$

4.33

 

$

5.36

 

Adjusted EBITDA (in thousands)

 

$

12,927

 

$

22,412

 

$

22,074

 

$

44,007

 

 

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

 

Powder River Basin — Adjusted EBITDA increased approximately 37% in the third quarter and 59% in the first three quarters of 2015 when compared to the third quarter and first three quarters of 2014.  Pricing improved slightly in the current quarter and more significantly in the current year-to-date period primarily due to the annual roll off and replacement of sales orders for 2015 occurring at a time of relatively favorable pricing following harsh winter weather in early 2014.  Low current year spot pricing has reduced the favorability of pricing in the current quarter.  Shipment volume increased slightly and cost per ton sold decreased in the third quarter of 2015 when compared to the third quarter of 2014. Unit costs are lower in the third quarter of 2015 primarily due to lower diesel fuel pricing and cost control efforts.  For the first three quarters of 2015, shipment volume and cost per ton sold were favorable to the first three quarters of 2014 due to strong carryover business from the prior year contributing to relatively robust demand in the first quarter of 2015 and lower diesel fuel pricing.  Our strategy of protecting against oil price spikes while preserving downside price participation has allowed us to benefit from the decrease in oil pricing in the current periods versus the prior year periods.  See further information regarding diesel fuel hedging strategies in Item 3. “Quantitative and Qualitative Disclosures About Market Risk.”

 

Appalachia — Adjusted EBITDA more than tripled in the third quarter and increased approximately 37% in the first three quarters of 2015 when compared to the third quarter and first three quarters of 2014.  Shipment volume and coal sales per ton sold both declined in the current year periods versus the prior year. Coal sales volumes decreased in the third quarter and first three quarters of 2015 when compared to the third quarter and first three quarters of 2014, due to the sale of one complex in the first quarter of 2014 and the idling of two complexes impacting the comparative periods.  Pricing declined in the third quarter and first three quarters of 2015 compared to the third quarter and first three quarters of 2014 across all major quality specifications.  Low natural gas prices in the current year period negatively impacted regional demand and pricing for thermal coal.  Oversupply in the Asian metallurgical coal market further depressed metallurgical pricing in the third quarter of 2015.  Meanwhile, the relative strength of the US dollar, and low dry bulk shipping rates continued to support Australian competition in the Atlantic metallurgical coal market.  Unit cost decreased significantly in the current quarter and the first three quarters of 2015 compared to the prior year periods.  The cost decrease in the third quarter of 2015  and the first three quarters of 2015 is due to increased productivity at both longwall mines and the shift in production to lower cost operations, particularly the Leer complex.  Adjusted EBITDA in the first three quarters of 2014 includes gains from the sale of a thermal coal complex and idled thermal coal mine in Kentucky ($15.6 million).  The Sycamore No. 2 Mine was idled early in the second quarter of 2015.

 

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Other — Adjusted EBITDA decreased approximately 42% in the third quarter and 50% in the first three quarters of 2015 when compared to the third quarter and first three quarters of 2014.  Sales volume increased slightly in the current year quarter, but declined in the first three quarters of 2015 compared to the first three quarters of 2014.  Unit cost increased in the current year periods due to reduced production volume in both the three-month and nine-month periods, and lower shipment volume in the first three quarters of 2015.  Pricing decreased in the third quarter of 2015 when compared to the third quarter of 2014 due to the ongoing market weakness.  Pricing increased in the first three quarters of 2015 when compared to the first three quarters of 2014 due to a favorable mix of customer shipments in the first quarter of 2015.

 

Results of Operations

 

Three Months Ended September 30, 2015 Compared to Three Months Ended September 30, 2014

 

Revenues.  Our revenues consist of coal sales.  The following table summarizes information about our coal sales during the three months ended September 30, 2015 and compares it with the information for the three months ended September 30, 2014:

 

 

 

Three Months Ended September 30,

 

 

 

 

 

2015

 

2014

 

(Decrease) / Increase

 

 

 

(In thousands)

 

Coal sales

 

688,544

 

$

742,180

 

$

(53,636

)

Tons sold

 

34,802

 

35,128

 

(326

)

 

On a consolidated basis, coal sales decreased in the third quarter of 2015 from the third quarter of 2014, due to the reduction in Appalachian volume and pricing of approximately $67 million.  The decrease in Appalachian coal sales is approximately 56% thermal related and 44% metallurgical related.  Volume and pricing improvement in the Powder River Basin and Other regions offset approximately $13MM of the decline in Appalachia.  See discussion in “Regional Performance” for further information about regional results.

 

Costs, expenses and other.  The following table summarizes costs, expenses and other components of operating income for the three months ended September 30, 2015 and compares it with the information for the three months ended September 30, 2014:

 

 

 

Three Months Ended September 30,

 

(Increase) Decrease

 

 

 

2015

 

2014

 

in Net Loss

 

 

 

(In thousands)

 

Cost of sales (exclusive of items shown separately below)

 

$

540,192

 

$

647,096

 

$

106,904

 

Depreciation, depletion and amortization

 

103,965

 

105,155

 

1,190

 

Amortization of acquired sales contracts, net

 

(1,994

)

(3,013

)

(1,019

)

Change in fair value of coal derivatives and coal trading activities, net

 

(3,559

)

(3,733

)

(174

)

Asset impairment and mine closure costs

 

2,120,292

 

5,060

 

(2,115,232

)

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

––

 

(149,314

)

Selling, general and administrative expenses

 

25,731

 

28,136

 

2,405

 

Other operating (income) expense, net

 

(8,625

)

(1,221

)

7,404

 

Total costs, expenses and other

 

$

2,925,316

 

$

777,480

 

$

(2,147,836

)

 

Cost of sales.  Our cost of sales decreased in the third quarter of 2015 from the third quarter of 2014 due to improved productivity at our Appalachian longwall operations (a decrease in Cost of Sales of approximately $46 million), lower diesel

 

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Table of Contents

 

fuel costs (approximately $23 million), savings associated with two idled Appalachian complexes (approximately $21 million), reduced coal purchases (approximately $11 million), and other savings associated with cost control efforts across all regions.  See discussion in “Regional Performance” for further information about regional results.

 

Depreciation, depletion and amortization.  When compared with the third quarter of 2014, depreciation, depletion and amortization costs decreased in 2015 due to reduced depreciation related to mine idlings and ongoing low levels of capital expenditures.

 

Asset impairment and mine closure costs.  Continued market deterioration, particularly for Appalachian products, was an indicator of impairment of certain assets.  Our testing indicated impairment of several active and undeveloped properties.  Impairment costs in the third quarter of 2015 include a significant portion of our assets at two current operating complexes, and a significant portion of our undeveloped coal reserves value.  See Note 5, “Asset Impairment and Mine Closure Costs” to the condensed consolidated financial statements for further discussion.

 

Losses from disposed operations relating to Patriot Coal bankruptcy. In the current quarter we recorded liabilities for surety bond and employee obligations that we expect to incur as a result of the Patriot Coal bankruptcy. See further information regarding the losses related to the Patriot Coal bankruptcy in Note 6, “Losses from disposed operations resulting form Patriot Coal bankruptcy” to the condensed consolidated financial statements.

 

Selling, general and administrative expenses. Total selling, general and administrative expenses decreased when compared with the third quarter of 2014, primarily due to lower compensation expense.

 

Other operating (income) expense, net.  Other operating expense for the three months ended September 30, 2015 includes a $24 million gain from a contract settlement, and increased cost for liquidated damages on logistics contracts of approximately $8 million.  Additionally, other operating income in the prior year quarter reflects the benefit from a net gain on sale of operations of approximately $2 million, and a net gain on the sale of various property, plant, and equipment of approximately $2 million.

 

Nonoperating Expense.  Nonoperating expenses in the third quarter of 2015 are related to our debt restructuring activities.  See further information regarding debt restructuring in Note 17, “Subsequent Events” to the condensed consolidated financial statements.

 

Benefit from income taxes.   The following table summarizes our benefit from income taxes for the three months ended September 30, 2015 and compares it with the information for the three months ended September 30, 2014:

 

 

 

Three Months Ended September 30,

 

Decrease

 

 

 

2015

 

2014

 

in Net Loss

 

 

 

(In thousands)

 

Benefit from income taxes

 

$

(343,865

)

$

(34,350

)

$

309,515

 

 

The income tax benefit rate of 14.7% in the third quarter of 2015 decreased from 26.1% in the third quarter of 2014 due to an increase in the percentage of calculated tax benefit subject to a valuation allowance.  See further discussion in Note 12, “Income Taxes”, to the condensed consolidated financial statements.

 

Nine Months Ended September 30, 2015 Compared to Nine Months Ended September 30, 2014

 

Revenues.  Our revenues consist of coal sales.  The following table summarizes information about our coal sales during the nine months ended September 30, 2015 and compares it with the information for the nine months ended September 30, 2014:

 

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Table of Contents

 

 

 

Nine Months Ended September 30,

 

 

 

 

 

2015

 

2014

 

(Decrease) / Increase

 

 

 

(In thousands)

 

Coal sales

 

$

2,010,011

 

$

2,189,989

 

$

(179,978

)

Tons sold

 

98,483

 

99,148

 

(665

)

 

On a consolidated basis, coal sales decreased in the first three quarters of 2015 from the first three quarters of 2014, due to the impact of reduced Appalachian volume and pricing of approximately $179 million. Volume reductions accounted for approximately 68% of the decrease and lower prices approximately 32% of the decrease.  Revenue variances from our other regions effectively offset, with the Powder River Basin increasing approximately $18 million and Other decreasing approximately $19 million.  See discussion in “Regional Performance” for further information about regional results.

 

Costs, expenses and other.  The following table summarizes costs, expenses and other components of operating income for the nine months ended September 30, 2015 and compares it with the information for the nine months ended September 30, 2014:

 

 

 

Nine Months Ended September 30,

 

(Increase) Decrease

 

 

 

2015

 

2014

 

in Net Loss

 

 

 

(In thousands)

 

Cost of sales (exclusive of items shown separately below)

 

$

1,668,766

 

$

1,955,547

 

$

286,781

 

Depreciation, depletion and amortization

 

306,211

 

312,042

 

5,831

 

Amortization of acquired sales contracts, net

 

(7,028

)

(9,948

)

(2,920

)

Change in fair value of coal derivatives and coal trading activities, net

 

(1,128

)

(5,811

)

(4,683

)

Asset impairment and mine closure costs

 

2,139,438

 

6,572

 

(2,132,866

)

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

149,314

 

––

 

(149,314

)

Selling, general and administrative expenses

 

72,604

 

87,203

 

14,599

 

Other operating (income) expense, net

 

7,864

 

(9,451

)

(17,315

)

Total costs, expenses and other

 

$

4,336,041

 

$

2,336,154

 

$

(1,999,887

)

 

Cost of sales.  Our cost of sales decreased in the first three quarters of 2015 from the first three quarters of 2014, due to lower transportation costs on lower export sales volumes (a decrease of approximately $64 million), lower diesel fuel costs (approximately $67 million), improved productivity at our Appalachian longwall operations (approximately $61 million), savings associated with one sold and two idled Appalachian complexes (approximately $70 million), and other savings associated with cost control efforts across all regions.  See discussion in “Regional Performance” for further information about regional results.

 

Depreciation, depletion and amortization.  When compared with the first three quarters of 2014, depreciation, depletion and amortization costs decreased in 2015 due to reduced depreciation in Appalachia related to mine idlings and ongoing low levels of capital expenditures.  The decrease was partially offset by increased depletion and depreciation in the Powder River Basin.

 

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Asset impairment and mine closure costs.  Please see the discussion in the comparison of results for the three month periods ended September 30, 2015 and 2014.  See Note 5, “Asset Impairment and Mine Closure Costs” to the condensed consolidated financial statements for further discussion.

 

Losses from disposed operations related to Patriot Coal bankruptcy. Please see the discussion in the comparison of results for the three month periods ended September 30, 2015 and 2014. See further information regarding losses related to the Patriot Coal bankruptcy in Note 6, “Losses from disposed operations resulting from Patriot Coal bankruptcy” to the condensed consolidated financial statements.

 

Selling, general and administrative expenses. Total selling, general and administrative expenses decreased when compared with the first three quarters of 2014, primarily due to lower compensation expenses.

 

Other operating (income) expense, net.  Other operating expense for the first three quarters of 2015 includes a $24 million gain on a contract settlement, and increased cost for liquidated damages on logistics contracts of approximately $12 million.  Additionally, the first three quarters of 2014 reflects the benefit from a net gain on sale of operations of approximately $14 million, and a net gain on sale of various property, plant, and equipment of approximately $8 million.

 

Nonoperating Expense.  Please see the discussion in the comparison of results for the three month periods ended September 30, 2015 and 2014.  See further information regarding debt restructuring in Note 17, “Subsequent Events” to the condensed consolidated financial statements.

 

Benefit from income taxes.   The following table summarizes our benefit from income taxes for the nine months ended September 30, 2015 and compares it with the information for the nine months ended September 30, 2014:

 

 

 

Nine Months Ended September 30,

 

Decrease

 

 

 

2015

 

2014

 

in Net Loss

 

 

 

(In thousands)

 

Benefit from income taxes

 

$

(351,332

)

$

(112,830

)

$

238,502

 

 

The income tax benefit rate of 13.3% in the first three quarters of 2015 decreased from 26.2% in the first three quarters of 2014 due to an increase in the percentage of calculated tax benefit subject to a valuation allowance.  See further discussion in Note 12, “Income Taxes”, to the condensed consolidated financial statements.

 

Reconciliation of NON-GAAP measures

 

Segment coal sales per ton sold

 

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

 

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Three Months Ended September
30,

 

Nine Months Ended
September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Reported segment coal sales revenues

 

$

641,969

 

$

701,402

 

$

1,877,726

 

$

1,995,836

 

Coal risk management derivative settlements classified in “other (income) expense, net”

 

(648

)

(502

)

(2,267

)

(4,700

)

Transportation costs

 

47,223

 

41,280

 

134,552

 

198,853

 

Coal sales

 

688,544

 

742,180

 

2,010,011

 

2,189,989

 

Other revenues

 

$

 

$

 

$

 

$

1,938

 

 

 

$

688,544

 

$

742,180

 

$

2,010,011

 

$

2,191,927

 

 

Segment cost per ton sold

 

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

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

 

 

 

 

 

 

 

 

 

 

Reported segment cost of tons sold

 

$

593,250

 

$

706,728

 

$

1,816,173

 

$

2,058,155

 

Diesel fuel risk management derivative settlements classified in “other (income) expense, net”

 

(2,684

)

(1,705

)

(4,894

)

(5,268

)

Transportation costs

 

47,223

 

41,280

 

134,552

 

198,853

 

Depreciation, depletion and amortization in reported segment cost of tons sold presented on separate line on statement of operations

 

(102,612

)

(103,328

)

(301,504

)

(308,931

)

Other (other operating segments, operating overhead, etc.)

 

5,015

 

4,121

 

24,439

 

12,738

 

Cost of sales

 

$

540,192

 

$

647,096

 

$

1,668,766

 

$

1,955,547

 

 

Segment Adjusted EBITDA to Net Income

 

The discussion in “Results of Operations” includes references to our Adjusted EBITDA. Adjusted EBITDA is defined as net income attributable to the Company before the effect of net interest expense, income taxes, depreciation, depletion and amortization and the amortization of acquired sales contracts. Adjusted EBITDA may also be adjusted for items that may not reflect the trend of future results. We believe that Adjusted EBITDA presents a useful measure of our ability to service and incur debt based on ongoing operations. 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.

 

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Table of Contents

 

 

 

Three Months Ended September 30,

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

2015

 

2014

 

 

 

(In thousands)

 

 

 

 

 

Reported Segment Adjusted EBITDA

 

$

140,886

 

$

97,511

 

$

329,982

 

$

246,937

 

Corporate and other

 

(6,081

)

(25,609

)

(68,077

)

(82,498

)

Adjusted EBITDA

 

134,805

 

71,902

 

261,905

 

164,439

 

Benefit from income taxes

 

343,865

 

34,350

 

351,332

 

112,830

 

Interest expense, net

 

(99,087

)

(96,268

)

(294,578

)

(286,820

)

Depreciation, depletion and amortization

 

(103,965

)

(105,155

)

(306,211

)

(312,042

)

Amortization of acquired sales contracts, net

 

1,994

 

3,013

 

7,028

 

9,948

 

Asset impairment and mine closure costs

 

(2,120,292

)

(5,060

)

(2,139,438

)

(6,572

)

Losses from disposed operations resulting from Patriot Coal bankruptcy

 

(149,314

)

––

 

(149,314

)

––

 

Nonoperating expense

 

(7,482

)

 

(11,498

)

 

Net loss

 

$

(1,999,476

)

$

(97,218

)

$

(2,280,774

)

$

(318,217

)

 

Corporate and other includes primarily selling, general and administrative expenses, income from our equity investments, certain actuarial adjustments, and certain changes in the fair value of coal derivatives and coal trading activities.  Corporate and other adjusted EBITDA increased $19.5 million in the third quarter 2015 when compared to the third quarter 2014 due to the $24 million gain on the settlement of a customer contract, and $2.4 million of reduced expenses recorded in the Statement of Operations line item “Selling, general and administrative expenses”.  These were partially offset by a $3.4 million negative adjustment to income from our equity investment in Millennium Bulk Terminal, increases in certain actuarial costs of $3.1 million, and $1.7 million in reduced gains from sale of property plant and equipment not associated with reporting segments.  The first three quarters of 2015 increased $14.4 million due to the $24 million settlement of a customer contract, $14.6 million of reduced expenses recorded in the Statement of Operations line item “Selling, general and administrative expenses”.  These were partially offset by a $3.4 million loss from our equity investment in Millennium Bulk Terminal, increases in certain actuarial costs of $11.1 million, a $4.7 million negative impact from changes in the fair value of coal derivatives and coal trading activities versus the prior year period, and $4.7 million in reduced gains from sale of property plant and equipment not associated with reporting segments.

 

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 have historically satisfied our working capital requirements and funded capital expenditures and debt-service obligations with cash generated from operations, cash on hand and credit extensions under our lines of credit (primarily our receivables securitization facility).  Our plans are subject to change based on our cash needs.  During the market down cycle our focus is preserving liquidity and prudently managing costs, including capital expenditures.  In addition, we regularly evaluate our capital structure and may make debt purchases for cash and /or exchanges for debt or equity from time to time through tender offers, open market purchases, private transactions, or otherwise, or seek to raise additional debt or equity, depending on market conditions and covenant restrictions.

 

We have no meaningful maturities of debt until 2018 and no financial maintenance covenants except under our $250 million revolver.  As of September 30, 2015, availability under our revolver was subject to limits on secured debt in our indentures.  At September 30, 2015, the limit under our most restrictive indenture did not provide meaningful availability under the revolver and, as a result, on November 6, 2015 we delivered an irrevocable 5 day notice to the administrative agent to voluntarily terminate all commitments thereunder, which will terminate on November 11, 2015.  We had no borrowings outstanding under our revolver credit facility at September 30, 2015 and had not been using it as a source of liquidity in the recent past.  At September 30, 2015 we had utilized $185.2 million of our $200.0 million receivables securitization facility for letters of credit.  We had liquidity of $704.4 million at September 30, 2015, with $694.5 million of that in cash and liquid securities.

 

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On July 2, 2015 we launched two private debt exchange offers in an effort to de-lever our balance sheet and improve our liquidity profile.  However, as a result of various factors, including the actions of our term lenders in directing the term loan agent not to execute required documents as well as highly challenging market conditions, the exchange offers were terminated.   Given these challenging market conditions, Arch will require significant restructuring of its balance sheet to continue to operate as a going concern over the long term.  We are currently in active dialogue with various creditors with respect to a restructuring of our balance sheet.  Our mining operations and customer shipments are continuing as normal and we continue to have a sizable amount of cash and no near-term maturities.

 

The following is a summary of cash provided by or used in each of the indicated types of activities during the nine months ended September 30,  2015 and 2014:

 

 

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

 

 

(In thousands)

 

Cash provided by (used in):

 

 

 

 

 

Operating activities

 

$

(79,682

)

$

1,990

 

Investing activities

 

(76,714

)

(87,980

)

Financing activities

 

(83,047

)

(29,175

)

 

Cash used in operating activities during the first three quarters 2015 was $79.7 million compared to cash provided from operating activities of $2.0 million in the first three quarters months of 2014.  The use of cash in operating activities was driven by increased use of cash in working capital compared to the prior year period, particularly inventory, approximately $71 million, and payables and other current liabilities, approximately $93 million. The increase was partially offset by increased Adjusted EBITDA of approximately $97 million, resulting from improved shipment volumes and pricing in the Powder River Basin, improved productivity in Appalachia, and lower diesel fuel pricing.

 

We used $76.7 million of cash in investing activities during the first nine months of 2015 compared to using $88.0 million of cash in the first nine months of 2014, due to increased net proceeds from marketable securities transactions of $48 million and lower capital expenditures of approximately $9 million largely offset by reduced proceeds from disposals and divestitures of approximately $50.0 million.  The divestitures of a Kentucky operation, idled assets, and our ADDCAR subsidiary are reflected in 2014 with no significant divestitures in 2015.

 

Cash used in financing activities increased $53.9 million in the first three quarters of 2015, compared to the first three quarters of 2014, as restricted cash increased $44.7 million and debt restructuring costs of $11.5 million were incurred.  These uses of cash were partially offset by the benefit from the elimination of the dividend on our common stock of $2.1 million, and approximately $2.2 million in debt financing costs incurred in the prior year period.

 

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Table of Contents

 

Ratio of Earnings to Fixed Charges

 

The following table sets forth our ratios of earnings to combined fixed charges and preference dividends for the periods indicated:

 

 

 

Nine Months Ended September 30,

 

 

 

2015

 

2014

 

Ratio of earnings to combined fixed charges and preference dividends(1)

 

N/A

 

N/A

(2)

 


(1)                                     Earnings consist of income from continuing operations before income taxes and are adjusted to include only distributed income from affiliates accounted for on the equity method and fixed charges (excluding capitalized interest). Fixed charges consist of interest incurred on indebtedness, the portion of operating lease rentals deemed representative of the interest factor and the amortization of debt expense.

 

(2)                                     Total losses for the ratio calculation round to $2,306.2 million and total fixed charges were $305.9 million for the nine months ended September 30, 2015.  Total losses for the ratio calculation were $123.5 million and total fixed charges were $301.1 million for the nine months ended September 30, 2014.

 

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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 2015 and 2016 were as follows as of October 22, 2015:

 

 

 

2015

 

2016

 

 

 

Tons

 

$ per ton

 

Tons

 

$ per ton

 

 

 

(in millions)

 

 

 

(in millions)

 

 

 

Powder River Basin

 

 

 

 

 

 

 

 

 

Committed, Priced

 

109.6

 

$

13.18

 

66.0

 

$

13.39

 

Committed, Unpriced

 

0.6

 

 

 

5.9

 

 

 

Appalachia

 

 

 

 

 

 

 

 

 

Committed, Priced Thermal

 

5.7

 

$

54.23

 

2.3

 

$

58.33

 

Committed, Unpriced Thermal

 

 

 

 

 

 

 

Committed, Priced Metallurgical

 

6.2

 

$

71.91

 

1.4

 

$

77.03

 

Committed, Unpriced Metallurgical

 

 

 

 

0.7

 

 

 

Other Bituminous

 

 

 

 

 

 

 

 

 

Committed, Priced

 

7.1

 

$

31.35

 

3.8

 

$

33.29

 

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 forward, swap and put and call option contracts at September 30, 2015. The estimated future realization of the value of the trading portfolio is $1.4 million of gains in the remainder of 2015 and $5.3 million of gains in 2016.

 

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 nine months ended September 30, 2015, VaR for our coal trading positions that are recorded at fair value through earnings ranged from under $0.1 million to $0.8 million. The linear mean of each daily VaR was $0.4 million. The final VaR at September 30, 2015 was $0.2 million.

 

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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 nine months ended September 30, 2015, VaR for our risk management positions that are recorded at fair value through earnings ranged from $0.1 million to $1.3 million. The linear mean of each daily VaR was $0.3 million. The final VaR at September 30, 2015 was $0.3 million.

 

We are also exposed to the risk of fluctuations in cash flows related to our purchase of diesel fuel. We expect to use approximately 55 to 65 million gallons per year of diesel fuel for use in our operations during 2015 and 2016. We enter into forward physical purchase contracts, as well as purchased heating oil options, to reduce volatility in the price of diesel fuel for our operations.  At September 30, 2015, we had protected the price of approximately 100% of its expected purchases for the remainder of the year with out-of-the-money call options with an average strike price of $3.13 per gallon.  Additionally, we have protected approximately 67% of our expected 2016 purchases with out-of-the-money call options with an average strike price of $2.26 per gallon .  At September 30, 2015, we had purchased heating oil call options for approximately 54 million gallons for the purpose of managing the price risk associated with future diesel purchases.  A $0.25 per gallon decrease in the price of heating oil would not result in an increase in our expense related to the heating oil derivatives.

 

We are exposed to market risk associated with interest rates due to our existing level of indebtedness. At September 30, 2015, of our $5.1 billion principal amount of debt outstanding, approximately $1.9 billion of outstanding borrowings have interest rates that fluctuate based on changes in the market rates. An increase in the interest rates related to these borrowings of 25 basis points would not result in an annualized increase in interest expense based on interest rates in effect at September 30, 2015, because our term loan has a minimum interest rate that exceeds the current market rates.

 

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 September 30, 2015.  Based on that evaluation, our management, including our chief executive officer and chief financial officer, concluded that the disclosure controls and procedures were effective as of such date. There were no changes in our internal control over financial reporting during the fiscal quarter to which this report relates that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

PART II

OTHER INFORMATION

 

Item 1.  Legal Proceedings.

 

In addition to the following matters, 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.  Also, as a result of historical acquisitions or dispositions by us or other companies in our industry, we may time to time be subject to claims or legal actions, including in respect of certain employee or retiree health or pension benefits.

 

Permit Litigation Matters

 

Surface mines at our Mingo Logan and Coal-Mac mining operations were identified in an existing lawsuit brought by the Ohio Valley Environmental Coalition (OVEC) in the U.S. District Court for the Southern District of West Virginia as having been granted Clean Water Act § 404 permits by the Army Corps of Engineers (Corps), allegedly in violation of the Clean Water

 

41



Table of Contents

 

Act and the National Environmental Policy Act.  The lawsuit, brought by OVEC in September 2005, originally was filed against the Corps for permits it had issued to four subsidiaries of a company unrelated to us or our operating subsidiaries.  The suit claimed that the Corps had issued permits to the subsidiaries of the unrelated company that did not comply with the National Environmental Policy Act and violated the Clean Water Act.

 

The court ruled on the claims associated with those four permits in orders of March 23 and June 13, 2007.  In the first of those orders, the court rescinded the four permits, finding that the Corps had inadequately assessed the likely impact of valley fills on headwater streams and had relied on inadequate or unproven mitigation to offset those impacts.  In the second order, the court entered a declaratory judgment that discharges of sediment from the valley fills into sediment control ponds constructed in-stream to control that sediment must themselves be permitted under a different provision of the Clean Water Act, § 402, and meet the effluent limits imposed on discharges from these ponds.  Both of the district court rulings were appealed to the U.S. Court of Appeals for the Fourth Circuit.

 

Before the court entered its first order, the plaintiffs were permitted to amend their complaint to challenge the Coal-Mac and Mingo Logan permits.  Plaintiffs sought preliminary injunctions against both operations, but later reached agreements with our operating subsidiaries that have allowed mining to progress in limited areas while the district court’s rulings were on appeal.  The claims against Coal-Mac were thereafter dismissed.

 

In February 2009, the Fourth Circuit reversed the District Court.  The Fourth Circuit held that the Corps’ jurisdiction under Section 404 of the Clean Water Act is limited to the narrow issue of the filling of jurisdictional waters.  The court also held that the Corps’ findings of no significant impact under the National Environmental Policy Act and no significant degradation under the Clean Water Act are entitled to deference.  Such findings entitle the Corps to avoid preparing an environmental impact statement, the absence of which was one issue on appeal.  These holdings also validated the type of mitigation projects proposed by our operations to minimize impacts and comply with the relevant statutes.  Finally, the Fourth Circuit found that stream segments, together with the sediment ponds to which they connect, are unitary “waste treatment systems,” not “waters of the United States,” and that the Corps had not exceeded its authority in permitting them.

 

OVEC sought rehearing before the entire appellate court, which was denied in May 2009, and the decision was given legal effect in June 2009.  An appeal to the U.S. Supreme Court was then filed in August 2009.  On August 3, 2010 OVEC withdrew its appeal.

 

Mingo Logan filed a motion for summary judgment with the district court in July 2009, asking that judgment be entered in its favor because no outstanding legal issues remained for decision as a result of the Fourth Circuit’s February 2009 decision.  By a series of motions, the United States obtained extensions and stays of the obligation to respond to the motion in the wake of its letters to the Corps dated September 3 and October 16, 2009 (discussed below).  By order dated April 22, 2010, the District Court stayed the case as to Mingo Logan for the shorter of either six months or the completion of the U.S. Environmental Protection Agency’s (EPA) proposed action to deny Mingo Logan the right to use its Corps’ permit (as discussed below).

 

On October 15, 2010, the United States moved to extend the existing stay for an additional 120 days (until February 22, 2011) while the EPA Administrator reviewed the “Recommended Determination” issued by the EPA Region 3.  By Memorandum Opinion and Order dated November 2, 2010, the court granted the United States’ motion.  On January 13, 2011, the EPA issued its “Final Determination” to withdraw the specification of two of the three watersheds as a disposal site for dredged or fill material approved under the current Section 404 permit.  The court was notified of the Final Determination and by order dated March 21, 2011 stayed further proceedings in the case until further order of the court, in light of the challenge to the EPA’s “Final Determination” then pending in federal court in Washington, DC.

 

In a Memorandum and Opinion and separate Order, each dated March 23, 2012, the federal court granted Mingo Logan’s motion for summary judgment, vacated EPA’s Final Determination and found valid and in full force Mingo Logan’s Section 404 permit.  As described more fully below, EPA appealed that order to the United States Court of Appeals for the DC circuit and by Opinion of the Court dated April 23, 2013, the court reversed the lower court’s order and remanded the matter to the district court for further proceedings.

 

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Table of Contents

 

On April 5, 2012, Mingo Logan moved to lift the stay referenced above.  On June 5, 2012, the Court entered an order lifting the stay and allowing the case to proceed on Mingo Logan’s Motion for Summary Judgment.  Shortly thereafter, OVEC filed a motion for leave to file a seventh amended and supplemental complaint seeking to update existing counts and raising two new claims (one, to enforce EPA’s “Final Determination” and, the other, that the Corps’ refusal to prepare a Supplemental Environmental Impact Statement violates the APA and NEPA).  By Memorandum, Opinion and Order dated July 25, 2012; the Court granted OVEC’s motion and directed the Clerk to file OVEC’s Seventh Amended and Supplemental Complaint.  Mingo Logan filed its Motion for Summary Judgment on August 31, 2012, along with its Answer to the Seventh Amended and Supplemental Complaint and the matter remains pending before the Court.

 

EPA Actions Related to Water Discharges from the Spruce Permit

 

By letter of September 3, 2009, the EPA asked the Corps of Engineers to suspend, revoke or modify the existing permit it issued in January 2007 to Mingo Logan under Section 404 of the Clean Water Act, claiming that “new information and circumstances have arisen which justify reconsideration of the permit.”  By letter of September 30, 2009, the Corps of Engineers advised the EPA that it would not reconsider its decision to issue the permit.  By letter of October 16, 2009, the EPA advised the Corps that it has “reason to believe” that the Mingo Logan mine will have “unacceptable adverse impacts to fish and wildlife resources” and that it intends to issue a public notice of a proposed determination to restrict or prohibit discharges of fill material that already are approved by the Corps’ permit.  By federal register publication dated April 2, 2010, the EPA issued its “Proposed Determination to Prohibit, Restrict or Deny the Specification, or the Use for Specification of an Area as a Disposal Site:  Spruce No. 1 Surface Mine, Logan County, WV” pursuant to Section 404(c) of the Clean Water Act, the EPA accepted written comments on its proposed action (sometimes known as a “veto proceeding”), through June 4, 2010 and conducted a public hearing, as well, on May 18, 2010.  We submitted comments on the action during this period.  On September 24, 2010, the EPA Region 3 issued a “Recommended Determination” to the EPA Administrator recommending that the EPA prohibit the placement of fill material in two of the three watersheds for which filling is approved under the current Section 404 permit.  Mingo Logan, along with the Corps, West Virginia DEP and the mineral owner, engaged in a consultation with the EPA as required by the regulations, to discuss “corrective action” to address the “unacceptable adverse effects” identified.  On January 13, 2011, the EPA issued its “Final Determination” pursuant to Section 404(c) of the Clean Water Act to withdraw the specification of two of the three watersheds approved in the current Section 404 permit as a disposal site for dredged or fill material.  By separate action, Mingo Logan sued the EPA on April 2, 2010 in federal court in Washington, D.C. seeking a ruling that the EPA has no authority under the Clean Water Act to veto a previously issued permit (Mingo Logan Coal Company, Inc. v. USEPA, No. 1:10-cv-00541(D.D.C.)).  The EPA moved to dismiss that action, and we responded to that motion.

 

Pursuant to a scheduling order for summary disposition of the case, motions and cross-motions for summary judgment by both parties were filed.  On November 30, 2011, the court heard arguments from the parties limited only to the threshold issue of whether the EPA had the authority under Section 404(c) of the Clean Water Act to withdraw the specification of the disposal site after the Corps had already issued a permit under Section 404(a).  The court deferred consideration of the remaining issue (i.e. whether the EPA’s “Final Determination” is otherwise lawful) until after consideration of the threshold issue.  On March 23, 2012, the court entered an Order and a Memorandum Opinion granting Mingo Logan’s motion for summary judgment, denying the EPA’s cross-motion for summary judgment, vacating the Final Determination and ordering that Mingo Logan’s Section 404 permit remains valid and in full force.

 

On May 11, 2012, the EPA filed a notice of appeal to the United States Court of Appeals for the District of Columbia Circuit.  The court heard oral arguments on March 14, 2013.  By opinion of the court filed on April 23, 2013, the court reversed the district court on the threshold issue and remanded the matter to the district court to address the merits of our APA challenge to the Final Determination.  On June 6, 2013, Mingo Logan filed a Petition for Rehearing En Banc and by Order filed July 25, 2013, the court denied the petition.

 

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On November 13, 2013, Mingo Logan filed a Petition for Writ of Certiorari with the Supreme Court of the United States seeking review of the DC Circuit’s decision.  On March 24, 2014, the Supreme Court denied Mingo Logan’s Petition for Writ of Certiorari and remanded the matter to the federal district court for the District of Columbia for further consideration on the merits of the Final Determination.  On September 30, 2014, the court entered an opinion and order denying Mingo Logan’s motion for summary judgment and granting the government’s motion for summary judgment.  The court upheld the Final Determination finding that EPA’s decision to withdraw the specifications for filling in Oldhouse Branch and Pigeonroost Branch under Mingo Logan’s Section 404 permit was not arbitrary and capricious.  On November 11, 2014, Mingo Logan filed a notice of appeal to the United States Court of Appeals for the District of Columbia Circuit Court.  On June 12, 2015, Mingo Logan filed its opening brief with the court.

 

UMWA 1974 Pension Plan et al. v Peabody Energy and Arch

 

On July 16, 2015, the UMWA 1974 Pension Trust (“Plan”) and its Trustees filed a Complaint for Declaratory Judgment against Peabody Energy Corporation, Peabody Holding Company, LLC and Arch, in the U.S. District Court in Washington D.C., seeking an order from the court requiring the defendants to submit to arbitration to determine their responsibility for pension withdrawal liability (triggered by Patriot Coal Corporation’s (“Patriot”) recent bankruptcy filing) for Plan participants of Patriot who formerly worked for Peabody and Arch subsidiaries.  In the alternative, the complaint asks the court to declare that Peabody and Arch are liable for Patriot’s withdrawal liability.   With respect to Arch, plaintiffs allege that Arch engaged in actions to avoid and evade pension fund withdrawal liability when it sold subsidiaries that were signatory to UMWA agreements, to Magnum Coal Company (“Magnum”) in 2005, in violation of ERISA law.  Patriot subsequently purchased Magnum in 2008.  On October 29, 2015, plaintiffs filed an amended complaint to reflect the allegations Patriot formally rejected its obligations to contribute to the Plan, triggering a withdrawal.  The amended complaint further alleged that Arch owes $299.8 million in withdrawal liability.  By letter dated October 29, 2015, the UMWA Funds issued a letter to Arch demanding payment of this withdrawal liability amount.  We believe there is no basis in the law to support any claim that Arch is responsible for Patriot’s withdrawal liability and we plan to vigorously defend this complaint.

 

Item 1A.  Risk Factors.

 

The risk factors set forth below are updates to the certain risk factors previously disclosed in Part I, Item IA. “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2014.

 

A loss or reduction in our ability to self-bond could have a material adverse effect on our business and results of operations.

 

Federal and state laws require us to obtain surety bonds or post letters of credit to secure performance or payment of certain long-term obligations, such as mine closure or reclamation costs, federal and state workers’ compensation costs, coal leases and other obligations. The costs of surety bonds have fluctuated in recent years while the market terms of such bonds have generally become more unfavorable to mine operators. These changes in the terms of the bonds have been accompanied at times by a decrease in the number of companies willing to issue surety bonds. We use self-bonding to secure performance of certain obligations in Wyoming. Self-bonding commits us to pay directly for reclamation costs rather than obtaining a traditional surety bond. As of December 31, 2014, we have self-bonded an aggregate of approximately $458.5 million. The Land Quality Division of the Wyoming Department of Environmental Quality periodically re-evaluates the amount of the bond, so the current amount is subject to increase.

 

There can be no assurance that the amount of our self-bonding obligations will not be increased or that we will continue to qualify to self-bond. To the extent we are unable to maintain our current level of self-bonding, due to legislative or regulatory changes or changes in our financial condition, our costs would increase and it could have a material adverse effect on our financial condition and results of operations, as well as cast substantial doubt on our ability to continue as a going concern.

 

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We have concluded that we need to restructure our balance sheet to continue as a going concern over the long term, but can provide no assurances of the terms thereof or how it will impact our securityholders.

 

As a result of extremely challenging current market conditions, Arch believes it will require a significant restructuring of its balance sheet in order to continue as a going concern in the long term.  We are currently in active dialogue with various creditors with respect to a restructuring of our balance sheet.  There can be no assurance that these efforts will result in any such agreement. If an agreement is reached and we pursue a restructuring, it may be necessary for us to file a voluntary petition for relief under Chapter 11 of the United States Bankruptcy Code in order to implement this agreement through the confirmation and consummation of a plan of reorganization approved by the bankruptcy court in the bankruptcy proceedings. We may also conclude that it is necessary to initiate Chapter 11 proceedings to implement a restructuring of our obligations even if we are unable to reach an agreement with our creditors and other relevant parties regarding the terms of such a restructuring. In either case, such a proceeding could be commenced in the near term.  If a plan of reorganization is implemented in a bankruptcy proceeding, it is likely that holders of claims and interests with respect to, or rights to acquire our equity securities, would likely be entitled to little or no recovery, and those claims and interests would likely be canceled for little or no consideration. If that were to occur, we anticipate that all, or substantially all, of the value of all investments in our common stock will be lost and that our equity holders would lose all or substantially all of their investment.  It is also likely that our other stakeholders, including our secured and unsecured creditors, will receive substantially less than the amount of their claims.

 

Our potential for restructuring transactions may impact our business, financial condition and operations.

 

Due to our potential for restructuring, there is risk that, among other things:

 

·                  third parties lose confidence in our ability to continue to produce coal, which could impact our ability to execute on our business strategy;

·                  it may become more difficult to attract, retain or replace key employees;

·                  employees could be distracted from performance of their duties or more easily attracted to other career opportunities;

·                  we could lose some or a significant portion of our liquidity, either due to stricter credit terms from suppliers, or, in the event we undertake a Chapter 11 proceeding and conclude that we need to procure but we cannot obtain any needed debtor-in-possession financing or provide adequate protection to certain secured lenders to permit us to access some or all of our cash; and

·                  our suppliers, hedge counterparties, vendors and service providers could seek to renegotiate the terms of our arrangements, terminate their relationship with us or require financial assurances from us.

 

The occurrence of certain of these events may have a material adverse effect on our business, results of operations and financial condition.

 

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

 

In September 2006, our board of directors authorized a share repurchase program for the purchase of up to 1,400,000 shares of our common stock. There is no expiration date on the current authorization, and we have not made any decisions to suspend or cancel purchases under the program. As of September 30, 2015, there were 1,092,580 shares of our common stock available for purchase under this program. We did not purchase any shares of our common stock under this program during the quarter ended September 30, 2015. Based on the closing price of our common stock as reported on the New York Stock Exchange on October 20, 2015, the approximate dollar value of our common stock that may yet be purchased under this program was $3.8 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 September 30, 2015.

 

Item 6.  Exhibits.

 

12.1

 

Computation of ratio of earnings to combined fixed charges and preference dividends.

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.

95.0

 

Mine Safety Disclosure Exhibit.

101.0

 

Interactive Data File (Form 10-Q for the three and nine months ended September 30, 2015 filed in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed.”

 

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Signatures

 

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

 

 

Arch Coal, Inc.

 

 

 

 

 

 

 

By:

/s/ John T. Drexler

 

 

John T. Drexler

 

 

Senior Vice President and Chief Financial Officer (On behalf of the registrant and as Principal Financial Officer)

 

 

 

 

 

November 9, 2015

 

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