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 June 30, 2014

 

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 July 31, 2014 there were 212,279,999 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

 

27

Item 3. Quantitative and Qualitative Disclosures About Market Risk

 

34

Item 4. Controls and Procedures

 

35

Part II OTHER INFORMATION

 

35

Item 1. Legal Proceedings

 

35

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

 

38

Item 4. Mine Safety Disclosures

 

38

Item 6. Exhibits

 

38

 

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 June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Unaudited)

 

Revenues

 

$

713,776

 

$

766,332

 

$

1,449,747

 

$

1,503,702

 

Costs, expenses and other operating

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

622,137

 

656,198

 

1,308,451

 

1,305,941

 

Depreciation, depletion and amortization

 

102,464

 

111,085

 

206,887

 

221,278

 

Amortization of acquired sales contracts, net

 

(3,239

)

(2,209

)

(6,935

)

(5,019

)

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

 

(2,992

)

(9,008

)

(2,078

)

(7,700

)

Asset impairment costs

 

1,512

 

20,482

 

1,512

 

20,482

 

Selling, general and administrative expenses

 

29,931

 

34,302

 

59,067

 

67,511

 

Other operating income, net

 

(232

)

(8,239

)

(8,230

)

(11,081

)

 

 

749,581

 

802,611

 

1,558,674

 

1,591,412

 

 

 

 

 

 

 

 

 

 

 

Loss from operations

 

(35,805

)

(36,279

)

(108,927

)

(87,710

)

Interest expense, net

 

 

 

 

 

 

 

 

 

Interest expense

 

(97,960

)

(94,756

)

(194,431

)

(189,830

)

Interest and investment income

 

2,036

 

1,216

 

3,879

 

4,052

 

 

 

(95,924

)

(93,540

)

(190,552

)

(185,778

)

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations before income taxes

 

(131,729

)

(129,819

)

(299,479

)

(273,488

)

Benefit from income taxes

 

(34,869

)

(49,468

)

(78,480

)

(108,821

)

Loss from continuing operations

 

(96,860

)

(80,351

)

(220,999

)

(164,667

)

Income from discontinued operations, net of tax

 

 

8,145

 

 

22,412

 

Net loss

 

$

(96,860

)

$

(72,206

)

$

(220,999

)

$

(142,255

)

 

 

 

 

 

 

 

 

 

 

Losses per common share

 

 

 

 

 

 

 

 

 

Basic and diluted LPS - Loss from continuing operations

 

$

(0.46

)

$

(0.38

)

$

(1.04

)

$

(0.78

)

 

 

 

 

 

 

 

 

 

 

Basic and diluted LPS - Net loss

 

$

(0.46

)

$

(0.34

)

$

(1.04

)

$

(0.67

)

 

 

 

 

 

 

 

 

 

 

Basic and diluted weighted average shares outstanding

 

212,225

 

212,082

 

212,198

 

212,072

 

 

 

 

 

 

 

 

 

 

 

Dividends declared per common share

 

$

 

$

0.03

 

$

0.01

 

$

0.06

 

 

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 June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Unaudited)

 

Net loss

 

$

(96,860

)

$

(72,206

)

$

(220,999

)

$

(142,255

)

 

 

 

 

 

 

 

 

 

 

Derivative instruments

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

1,007

 

(391

)

778

 

(1,570

)

Income tax benefit (provision)

 

(362

)

143

 

(280

)

568

 

 

 

645

 

(248

)

498

 

(1,002

)

Pension, postretirement and other post-employment benefits

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

(2,269

)

1,750

 

(4,116

)

3,704

 

Income tax benefit (provision)

 

817

 

(630

)

1,482

 

(1,333

)

 

 

(1,452

)

1,120

 

(2,634

)

2,371

 

Available-for-sale securities

 

 

 

 

 

 

 

 

 

Comprehensive income (loss) before tax

 

(1,203

)

4,959

 

(3,236

)

6,512

 

Income tax benefit (provision)

 

433

 

(1,788

)

1,165

 

(2,347

)

 

 

(770

)

3,171

 

(2,071

)

4,165

 

 

 

 

 

 

 

 

 

 

 

Total other comprehensive income (loss)

 

(1,577

)

4,043

 

(4,207

)

5,534

 

Total comprehensive loss

 

$

(98,437

)

$

(68,163

)

$

(225,206

)

$

(136,721

)

 

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)

 

 

 

June 30,

 

December 31,

 

 

 

2014

 

2013

 

 

 

(Unaudited)

 

Assets

 

 

 

 

 

Current assets

 

 

 

 

 

Cash and cash equivalents

 

$

740,154

 

$

911,099

 

Short term investments

 

248,647

 

248,414

 

Trade accounts receivable

 

203,782

 

198,020

 

Other receivables

 

35,369

 

31,553

 

Inventories

 

228,726

 

264,161

 

Prepaid royalties

 

7,932

 

8,083

 

Deferred income taxes

 

48,786

 

49,144

 

Coal derivative assets

 

14,122

 

14,851

 

Other current assets

 

54,270

 

56,746

 

Total current assets

 

1,581,788

 

1,782,071

 

Property, plant and equipment, net

 

6,603,458

 

6,734,286

 

Other assets

 

 

 

 

 

Prepaid royalties

 

87,494

 

87,577

 

Equity investments

 

229,514

 

221,456

 

Other noncurrent assets

 

153,854

 

164,803

 

Total other assets

 

470,862

 

473,836

 

Total assets

 

$

8,656,108

 

$

8,990,193

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

Current liabilities

 

 

 

 

 

Accounts payable

 

$

160,209

 

$

176,142

 

Accrued expenses and other current liabilities

 

294,317

 

278,587

 

Current maturities of debt

 

27,266

 

33,493

 

Total current liabilities

 

481,792

 

488,222

 

Long-term debt

 

5,116,353

 

5,118,002

 

Asset retirement obligations

 

395,813

 

402,713

 

Accrued pension benefits

 

13,925

 

7,111

 

Accrued postretirement benefits other than pension

 

38,034

 

39,255

 

Accrued workers’ compensation

 

74,083

 

78,062

 

Deferred income taxes

 

332,207

 

413,546

 

Other noncurrent liabilities

 

172,512

 

190,033

 

Total liabilities

 

6,624,719

 

6,736,944

 

Stockholders’ equity

 

 

 

 

 

Common stock, $0.01 par value, authorized 260,000 shares, issued 213,792 shares at both June 30, 2014 and December 31, 2013.

 

2,141

 

2,141

 

Paid-in capital

 

3,044,082

 

3,038,613

 

Treasury stock, at cost

 

(53,848

)

(53,848

)

Accumulated deficit

 

(994,471

)

(771,349

)

Accumulated other comprehensive income

 

33,485

 

37,692

 

Total stockholders’ equity

 

2,031,389

 

2,253,249

 

Total liabilities and stockholders’ equity

 

$

8,656,108

 

$

8,990,193

 

 

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)

 

 

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(Unaudited)

 

Operating activities

 

 

 

 

 

Net loss

 

$

(220,999

)

$

(142,255

)

Adjustments to reconcile net loss to cash provided by (used in) operating activities:

 

 

 

 

 

Depreciation, depletion and amortization

 

206,887

 

237,668

 

Amortization of acquired sales contracts, net

 

(6,935

)

(5,019

)

Amortization relating to financing activities

 

7,757

 

12,346

 

Prepaid royalties expensed

 

3,575

 

9,251

 

Employee stock-based compensation expense

 

5,469

 

5,804

 

Asset impairment costs

 

1,512

 

20,482

 

Gains on disposals and divestitures, net

 

(18,506

)

(2,819

)

Deferred income taxes

 

(78,568

)

(102,172

)

Changes in:

 

 

 

 

 

Receivables

 

267

 

(3,909

)

Inventories

 

3,522

 

8,771

 

Accounts payable, accrued expenses and other current liabilities

 

10,495

 

(4,062

)

Income taxes, net

 

(571

)

(29

)

Other

 

7,749

 

17,988

 

Cash provided by (used in) operating activities

 

(78,346

)

52,045

 

Investing activities

 

 

 

 

 

Capital expenditures

 

(95,746

)

(169,064

)

Payments of minimum royalties

 

(3,341

)

(10,162

)

Proceeds from sale-leaseback transactions

 

 

5,080

 

Proceeds from disposals and divestitures

 

43,245

 

34,919

 

Purchases of short term investments

 

(168,951

)

(61,870

)

Proceeds from sales of short term investments

 

166,018

 

47,097

 

Investments in and advances to affiliates

 

(9,501

)

(8,142

)

Change in restricted cash

 

 

2,368

 

Cash used in investing activities

 

(68,276

)

(159,774

)

Financing activities

 

 

 

 

 

Payments on term loan

 

(9,750

)

(8,250

)

Net payments on other debt

 

(9,390

)

(11,703

)

Debt financing costs

 

(1,957

)

 

Dividends paid

 

(2,123

)

(12,735

)

Change in restricted cash

 

(1,103

)

 

Cash used in financing activities

 

(24,323

)

(32,688

)

Decrease in cash and cash equivalents

 

(170,945

)

(140,417

)

Cash and cash equivalents, beginning of period

 

911,099

 

784,622

 

Cash and cash equivalents, end of period

 

$

740,154

 

$

644,205

 

 

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, Illinois, Wyoming and Colorado.  All subsidiaries are wholly-owned. Intercompany transactions and accounts have been eliminated in consolidation.

 

The Company completed the sale of Canyon Fuel Company, LLC (“Canyon Fuel”) on August 16, 2013.  The results of Canyon Fuel have been segregated from continuing operations and are reflected, net of tax, as discontinued operations in the condensed consolidated statements of operations for the three and six months ended June 30, 2013.

 

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States for interim financial reporting and U.S. Securities and Exchange Commission regulations. In the opinion of management, all adjustments, consisting of normal, recurring accruals considered necessary for a fair presentation, have been included. Results of operations for the three and six months ended June 30, 2014 are not necessarily indicative of results to be expected for the year ending December 31, 2014. 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, 2013 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

 

2.        Accounting Policies

 

In May 2014, the FASB issued comprehensive authoritative guidance for the recognition and presentation of revenue from contracts with customers. The revenue recognition model is based on changes in contract assets (right to receive consideration) and liabilities (obligations to provide a good or perform a service).  The guidance also requires comprehensive quantitative and qualitative disclosures intended to enable financial statement users to understand the nature, timing and uncertainty of revenue and the related cash flows. This guidance will be effective for the Company in the first fiscal quarter of 2017, with early adoption not permitted. The Company is currently assessing the impact the guidance will have upon adoption, but expects no significant changes to its existing revenue recognition policies.

 

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

 

Loss

 

 

 

(In thousands)

 

Balance at December 31, 2013

 

$

565

 

$

31,112

 

$

6,015

 

$

37,692

 

Unrealized gains (losses)

 

788

 

 

(3,146

)

(2,358

)

Amounts reclassified from AOCI

 

(290

)

(2,634

)

1,075

 

(1,849

)

Balance at June 30, 2014

 

$

1,063

 

$

28,478

 

$

3,944

 

$

33,485

 

 

The following amounts were reclassified out of AOCI:

 

7



Table of Contents

 

 

 

Amounts Reclassified from AOCI

 

Line Item in the

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

Condensed Consolidated

 

Details About AOCI

 

2014

 

2013

 

2014

 

2013

 

Statement of Operations

 

 

 

(In thousands)

 

 

 

Derivative instruments

 

$

151

 

$

542

 

$

454

 

$

1,401

 

Revenues

 

 

 

(55

)

(196

)

(164

)

(505

)

Benefit from income taxes

 

 

 

$

96

 

$

346

 

$

290

 

$

896

 

Net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

Pension, postretirement and other post-employment benefits

 

 

 

 

 

 

 

 

 

 

 

Amortization of prior service credits (1)

 

$

2,591

 

$

2,673

 

$

5,217

 

$

5,581

 

 

 

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

 

(321

)

(4,423

)

(1,100

)

(9,285

)

 

 

 

 

2,270

 

(1,750

)

4,116

 

(3,704

)

 

 

 

 

(817

)

630

 

(1,482

)

1,333

 

Benefit from income taxes

 

 

 

$

1,453

 

$

(1,120

)

$

2,634

 

$

(2,371

)

Net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

Available-for-sale securities (2)

 

$

(1,123

)

$

(250

)

$

(1,679

)

$

(309

)

Interest and investment income

 

 

 

404

 

90

 

604

 

111

 

Benefit from income taxes

 

 

 

$

(719

)

$

(160

)

$

(1,075

)

$

(198

)

Net of tax

 

 


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

2 The gains and losses on sales of available-for-sale-securities are determined on a specific identification basis.

 

8



Table of Contents

 

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 during the first quarter of 2014 for total consideration of $45.3 million.  The Company has received $34.2 million in cash, and the remaining $11.0 million is payable on December 31, 2014.  The Company recognized a net pre-tax gain of $12.8 million from these divestitures, reflected in “other operating income, net” in the condensed consolidated statement of operations.

 

The following table summarizes the assets and liabilities of the divested operations reflected in the December 31, 2013 consolidated balance sheet (in thousands):

 

Inventories

 

$

33,283

 

Other current assets

 

1,032

 

Net property, plant & equipment

 

104,587

 

Other noncurrent assets

 

139

 

Accounts payable and accrued expenses

 

13,005

 

Other noncurrent liabilities

 

24,276

 

 

The following table summarizes the results of Canyon Fuel, reflected as discontinued operations in the condensed consolidated statement of operations through the date of disposition:

 

 

 

Three Months Ended
June 30, 2013

 

Six Months Ended
June 30, 2013

 

 

 

(in thousands)

 

Total revenues

 

$

85,107

 

$

173,239

 

Income from discontinued operations before income taxes

 

$

9,748

 

$

28,737

 

Less: income tax expense

 

1,603

 

6,325

 

Income from discontinued operations

 

$

8,145

 

$

22,412

 

Basic and diluted earnings per common share from discontinued operations

 

$

0.04

 

$

0.11

 

 

5.        Inventories

 

Inventories consist of the following:

 

 

 

June 30,

 

December 31

 

 

 

2014

 

2013

 

 

 

(In thousands)

 

Coal

 

$

101,195

 

$

117,531

 

Repair parts and supplies

 

127,531

 

137,497

 

Work-in-process

 

 

9,133

 

 

 

$

228,726

 

$

264,161

 

 

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $8.7 million at June 30, 2014 and $8.4 million at December 31, 2013.

 

6.              Investments in Available-for-Sale Securities

 

The Company has invested in marketable debt securities, primarily highly liquid AA - rated corporate bonds and U.S. government and government agency securities.  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.

 

9



Table of Contents

 

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

 

 

 

June 30, 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

 

$

251,038

 

$

 

$

(2,391

)

$

248,647

 

$

248,647

 

$

 

Equity securities

 

5,420

 

11,245

 

(2,701

)

13,964

 

 

13,964

 

Total Investments

 

$

256,458

 

$

11,245

 

$

(5,092

)

$

262,611

 

$

248,647

 

$

13,964

 

 

 

 

December 31, 2013

 

 

 

 

 

 

 

 

 

 

 

Balance Sheet

 

 

 

 

 

Gross

 

Gross

 

 

 

Classification

 

 

 

 

 

Unrealized

 

Unrealized

 

Fair

 

Short-Term

 

Other

 

 

 

Cost Basis

 

Gains

 

Losses

 

Value

 

Investments

 

Assets

 

 

 

(In thousands)

 

Available-for-sale:

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S. government and agency securities

 

$

65,002

 

$

11

 

$

(75

)

$

64,938

 

$

64,938

 

$

 

Corporate notes and bonds

 

184,773

 

7

 

(1,304

)

183,476

 

183,476

 

 

Equity securities

 

5,271

 

13,660

 

(2,902

)

16,029

 

 

16,029

 

Total Investments

 

$

255,046

 

$

13,678

 

$

(4,281

)

$

264,443

 

$

248,414

 

$

16,029

 

 

The aggregate fair value of investments with unrealized losses that were owned for less than a year was $242.5 million and $164.3 million at June 30, 2014 and December 31, 2013, 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 $6.5 million and $48.7 million at June 30, 2014 and December 31, 2013, respectively.

 

The debt securities outstanding at June 30, 2014 have maturity dates ranging from the third quarter of 2014 through the fourth quarter of 2015.  The Company classifies its investments as current based on the nature of the investments and their availability to provide cash for use in current operations.

 

7.              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 57 to 67 million gallons of diesel fuel for use in its operations during 2014. To protect the Company’s cash flows from increases in the price of diesel fuel for its operations, the Company uses forward physical diesel purchase contracts and purchased heating oil call options. At June 30, 2014, the Company had protected the price of approximately 88% of its expected purchases for the remainder of 2014 and 80% of its expected 2015 purchases through the third quarter.  At June 30, 2014, the Company had purchased heating oil call options for approximately 70 million gallons for the purpose of managing the price risk associated with future diesel purchases.

 

The Company has also purchased heating oil call options to manage the price risk associated with fuel surcharges on its barge and rail shipments, which cover increases in diesel fuel prices for the respective carriers. At June 30, 2014, the Company held heating oil call options for 3.4 million gallons that will settle ratably through February 2015 for the purpose of managing the fluctuations in cash flows associated with fuel surcharges on future shipments.

 

These positions reduce the Company’s risk of cash flow fluctuations related to these surcharges but the positions are not accounted for as hedges.

 

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Coal price risk management positions

 

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

 

At June 30, 2014, the Company held derivatives for risk management purposes that are expected to settle in the following years:

 

(Tons in thousands)

 

2014

 

2015

 

Total

 

Coal sales

 

2,504

 

2,380

 

4,884

 

Coal purchases

 

1,308

 

360

 

1,668

 

 

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 $6.3 million of gains during the remainder of 2014 and $2.9 million of gains in 2015.

 

Tabular derivatives disclosures

 

The Company has master netting agreements with all of its counterparties which allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default or termination. Such netting arrangements reduce the Company’s credit exposure related to these counterparties. For classification purposes, the Company records the net fair value of all the positions with a given counterparty as a net asset or liability in the condensed consolidated balance sheets. The amounts shown in the table below represent the fair value position of individual contracts, and not the net position presented in the accompanying condensed consolidated balance sheets. The fair value and location of derivatives reflected in the accompanying condensed consolidated balance sheets are as follows:

 

 

 

June 30, 2014

 

 

 

December 31, 2013

 

 

 

Fair Value of Derivatives

 

Asset

 

Liability

 

 

 

Asset

 

Liability

 

 

 

(In thousands)

 

Derivative

 

Derivative

 

 

 

Derivative

 

Derivative

 

 

 

Derivatives Designated as Hedging Instruments

 

 

 

 

 

 

 

 

 

 

 

 

 

Coal

 

$

1,770

 

$

(360

)

 

 

$

909

 

$

(26

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives Not Designated as Hedging Instruments

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating oil — diesel purchases

 

4,250

 

 

 

 

4,681

 

 

 

 

Heating oil — fuel surcharges

 

104

 

 

 

 

422

 

 

 

 

Coal — held for trading purposes

 

72,881

 

(63,749

)

 

 

55,327

 

(45,763

)

 

 

Coal — risk management

 

4,952

 

(1,715

)

 

 

6,342

 

(1,950

)

 

 

Natural gas

 

343

 

 

 

 

 

 

 

 

Total

 

82,530

 

(65,464

)

 

 

66,772

 

(47,713

)

 

 

Total derivatives

 

84,300

 

(65,824

)

 

 

67,681

 

(47,739

)

 

 

Effect of counterparty netting

 

(65,824

)

65,824

 

 

 

(47,727

)

47,727

 

 

 

Net derivatives as classified in the balance sheets

 

$

18,476

 

$

 

$

18,476

 

$

19,954

 

$

(12

)

$

19,942

 

 

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June 30, 2014

 

December 31,
2013

 

Net derivatives as reflected on the balance sheets

 

 

 

 

 

 

 

Heating oil

 

Other current assets

 

$

4,354

 

$

5,103

 

Coal

 

Coal derivative assets

 

14,122

 

14,851

 

 

 

Accrued expenses and other current liabilities

 

 

(12

)

 

 

 

 

$

18,476

 

$

19,942

 

 

The Company had a current liability for the obligation to post cash collateral of $1.9 million at June 30, 2014 and a current asset for the right to reclaim cash collateral of $2.2 million at December 31, 2013. These amounts are not included with the derivatives presented in the table above and are included in “accrued expenses and other current liabilities” and “other current assets”, respectively, in the accompanying condensed consolidated balance sheets.

 

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

 

Derivatives used in Cash Flow Hedging Relationships (in thousands)

Three Months Ended June 30,

 

 

 

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

 

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

 

 

 

2014

 

2013

 

2014

 

2013

 

Coal sales(1)

 

$

1,870

 

$

(648

)

$

223

 

$

690

 

Coal purchases(2)

 

(712

)

613

 

(72

)

(148

)

Totals

 

$

1,158

 

$

(35

)

$

151

 

$

542

 

 

No ineffectiveness or amounts excluded from effectiveness testing relating to the Company’s cash flow hedging relationships were recognized in the results of operations in the three month periods ended June 30, 2014 and 2013.

 

Derivatives Not Designated as Hedging Instruments (in thousands)

Three Months Ended June 30,

 

 

 

Gain (Loss) Recognized

 

 

 

2014

 

2013

 

Coal — unrealized(3)

 

$

147

 

$

4,109

 

Coal — realized(4)

 

$

1,318

 

$

6,579

 

Natural gas  — unrealized(3)

 

$

(267

)

$

 

Heating oil — diesel purchases(4)

 

$

 

$

(5,211

)

Heating oil — fuel surcharges(4)

 

$

(47

)

$

(30

)

 


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, net

 

Derivatives used in Cash Flow Hedging Relationships (in thousands)

Six Months Ended June 30,

 

 

 

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

 

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

 

 

 

2014

 

2013

 

2014

 

2013

 

Coal sales(1)

 

$

1,355

 

$

(824

)

$

930

 

$

1,911

 

Coal purchases(2)

 

(123

)

431

 

(476

)

(510

)

Totals

 

$

1,232

 

$

(393

)

$

454

 

$

1,401

 

 

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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 six month periods ended June 30, 2014 and 2013.

 

Derivatives Not Designated as Hedging Instruments (in thousands)

Six Months Ended June 30,

 

 

 

Gain (Loss) Recognized

 

 

 

2014

 

2013

 

Coal — unrealized(3)

 

$

(1,155

)

$

5,579

 

Coal — realized(4)

 

$

4,197

 

$

15,796

 

Natural gas  — unrealized(3)

 

$

(259

)

$

 

Heating oil — diesel purchases(4)

 

$

(2,963

)

$

(9,472

)

Heating oil — fuel surcharges(4)

 

$

(301

)

$

(595

)

 


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, net

 

Based on fair values at June 30, 2014, gains on derivative contracts designated as hedge instruments in cash flow hedges of approximately $0.8 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 $3.1 million and $4.9 million during the three months ended June 30, 2014 and 2013, respectively; and net unrealized and realized gains of $3.5 million and $2.1 million during the six months ended June 30, 2014 and 2013.  Gains and losses from trading activities are included in the caption “Change in fair value of coal derivatives and coal trading activities, net” in the accompanying condensed consolidated statements of operations, and are not included in the previous tables reflecting the effects of derivatives on measures of financial performance.

 

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8.              Accrued Expenses and Other Current Liabilities

 

Accrued expenses and other current liabilities consist of the following:

 

 

 

June 30,

 

December 31,

 

 

 

2014

 

2013

 

 

 

(In thousands)

 

Payroll and employee benefits

 

$

62,486

 

$

67,621

 

Taxes other than income taxes

 

116,176

 

114,664

 

Interest

 

32,765

 

18,528

 

Acquired sales contracts

 

13,468

 

14,373

 

Workers’ compensation

 

17,783

 

12,434

 

Asset retirement obligations

 

22,682

 

24,940

 

Other

 

28,957

 

26,027

 

 

 

$

294,317

 

$

278,587

 

 

9.         Debt and Financing Arrangements

 

 

 

June 30,

 

December 31,

 

 

 

2014

 

2013

 

 

 

(In thousands)

 

Term loan due 2018 ($1.92 billion and $1.93 billion face value, respectively)

 

$

1,898,697

 

$

1,906,975

 

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)

 

362,867

 

362,358

 

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

 

32,055

 

32,162

 

 

 

5,143,619

 

5,151,495

 

Less current maturities of debt

 

27,266

 

33,493

 

Long-term debt

 

$

5,116,353

 

$

5,118,002

 

 

At June 30, 2014, the available borrowing capacity under the Company’s lines of credit was approximately $248.4 million.

 

10.            Income taxes

 

During the first quarter of 2014, the Company determined it was more likely than not that a portion of the federal and state net operating losses it expects to generate in 2014 will not be realized based on projections of future taxable income.  Accordingly, the estimated annual effective rate for the year ended December 31, 2014 includes a valuation allowance for that portion.  In applying the estimated annual effective rate to earnings, the Company increased its valuation allowance by $18.3 million for the three months ended June 30, 2014 and $42.1 million for the six months ended June 30, 2014 relating to federal and state net operating losses.

 

11.       Fair Value Measurements

 

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

 

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

 

·                  Level 2 is defined as observable inputs other than Level 1 prices. These include quoted prices for similar assets or liabilities in an active market, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that

 

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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 June 30, 2014.

 

The table below sets forth, by level, the Company’s financial assets and liabilities that are recorded at fair value in the accompanying condensed consolidated balance sheet:

 

 

 

June 30, 2014

 

 

 

Total

 

Level 1

 

Level 2

 

Level 3

 

 

 

(In thousands)

 

Assets:

 

 

 

 

 

 

 

 

 

Investments in marketable securities

 

$

262,611

 

$

13,964

 

$

248,647

 

$

 

Derivatives

 

18,476

 

12,653

 

(214

)

6,037

 

Total assets

 

$

281,087

 

$

26,617

 

$

248,433

 

$

6,037

 

 

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

 

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

 

 

 

Three Months Ended
June 30, 2014

 

Six Months Ended June
30, 2014

 

 

 

(In thousands)

 

 

 

Balance, beginning of period

 

$

3,977

 

$

4,946

 

Realized and unrealized losses recognized in earnings, net

 

205

 

(2,720

)

Purchases

 

1,855

 

3,811

 

Ending balance

 

$

6,037

 

$

6,037

 

 

Net unrealized gains of $0.5 million and losses of $1.6 million were recognized during the three and six months ended June 30, 2014, respectively, related to level 3 financial instruments held on June 30, 2014.

 

Fair Value of Long-Term Debt

 

At June 30, 2014 and December 31, 2013, the fair value of the Company’s debt, including amounts classified as current, was $4.5 billion and $4.6 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.

 

12.            Loss Per Common Share

 

The effect of options, restricted stock and restricted stock units equaling 7.0 million shares of common stock were excluded from the calculation of diluted weighted average shares outstanding for the three and six months ended June 30, 2014 and 7.0 million and 8.4 million shares for the three and six months ended June 30, 2013, respectively, because the exercise price or grant price of the securities exceeded the average market price of the Company’s common stock for these periods. 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 six months ended June 30, 2014 were 2.9 million and 2.2 million, respectively.  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 six months ended June 30, 2013 were not significant.

 

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13.       Employee Benefit Plans

 

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

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

Service cost

 

$

5,477

 

$

6,790

 

$

11,401

 

$

14,490

 

Interest cost

 

4,192

 

3,876

 

8,556

 

7,802

 

Expected return on plan assets

 

(5,879

)

(6,036

)

(11,857

)

(11,842

)

Amortization of prior service costs (credits)

 

(53

)

57

 

(107

)

(101

)

Amortization of other actuarial losses

 

532

 

4,264

 

1,480

 

8,815

 

Net benefit cost

 

$

4,269

 

$

8,951

 

$

9,473

 

$

19,164

 

 

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

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

Service cost

 

$

440

 

$

538

 

$

884

 

$

1,094

 

Interest cost

 

457

 

415

 

921

 

846

 

Amortization of prior service credits

 

(2,501

)

(2,730

)

(5,002

)

(5,480

)

Amortization of other actuarial losses (gains)

 

(210

)

(75

)

(380

)

2

 

Net benefit credit

 

$

(1,814

)

$

(1,852

)

$

(3,577

)

$

(3,538

)

 

14.            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.

 

Allegheny Energy Supply (“Allegheny”), the sole customer of coal produced at the Company’s subsidiary Wolf Run Mining Company’s (“Wolf Run”) Sycamore No. 2 mine, filed a lawsuit against Wolf Run, Hunter Ridge Holdings, Inc. (“Hunter Ridge”), and ICG in state court in Allegheny County, Pennsylvania on December 28, 2006, and amended its complaint on April 23, 2007. Allegheny claimed that Wolf Run breached a coal supply contract when it declared force majeure under the contract upon idling the Sycamore No. 2 mine in the third quarter of 2006, and that Wolf Run continued to breach the contract by failing to ship in volumes referenced in the contract.  The Sycamore No. 2 mine was idled after encountering adverse geologic conditions and abandoned gas wells that were previously unidentified and unmapped.

 

After extensive searching for gas wells and rehabilitation of the mine, it was re-opened in 2007, but with notice to Allegheny that it would necessarily operate at reduced volumes in order to safely and effectively avoid the many gas wells within the reserve.  The amended complaint also alleged that the production stoppages constitute a breach of the guarantee agreement by Hunter Ridge and breach of certain representations made upon entering into the contract in early 2005. Allegheny voluntarily dropped the breach of representation claims later.  Allegheny claimed that it would incur costs in excess of $100 million to purchase replacement coal over the life of the contract.  ICG, Wolf Run and Hunter Ridge answered the amended complaint on August 13, 2007, disputing all of the remaining claims.

 

On November 3, 2008, ICG, Wolf Run and Hunter Ridge filed an amended answer and counterclaim against the plaintiffs seeking to void the coal supply agreement due to, among other things, fraudulent inducement and conspiracy.  On September 23, 2009, Allegheny filed a second amended complaint alleging several alternative theories of liability in its effort to extend contractual liability to ICG, which was not a party to the original contract and did not exist at the time Wolf Run and Allegheny entered into the contract.  No new substantive claims were asserted.  ICG answered the second amended complaint

 

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on October 13, 2009, denying all of the new claims.  The Company’s counterclaim was dismissed on motion for summary judgment entered on May 11, 2010.  Allegheny’s claims against ICG were also dismissed by summary judgment, but the claims against Wolf Run and Hunter Ridge were not.  The court conducted a non-jury trial of this matter beginning on January 10, 2011 and concluding on February 1, 2011.

 

At the trial, Allegheny presented its evidence for breach of contract and claimed that it is entitled to past and future damages in the aggregate of between $228 million and $377 million.  Wolf Run and Hunter Ridge presented their defense of the claims, including evidence with respect to the existence of force majeure conditions and excuse under the contract and applicable law.  Wolf Run and Hunter Ridge presented evidence that Allegheny’s damages calculations were significantly inflated because it did not seek to determine damages as of the time of the breach and in some instances artificially assumed future nondelivery or did not take into account the apparent requirement to supply coal in the future.  On May 2, 2011, the trial court entered a Memorandum and Verdict determining that Wolf Run had breached the coal supply contract and that the performance shortfall was not excused by force majeure.  The trial court awarded total damages and interest in the amount of $104.1 million, which consisted of $13.8 million for past damages, and $90.3 million for future damages.  ICG and Allegheny filed post-verdict motions in the trial court and on August 23, 2011, the court denied the parties’ motions.  The court entered a final judgment on August 25, 2011, in the amount of $104.1 million, which included pre-judgment interest.

 

The parties appealed the lower court’s decision to the Superior Court of Pennsylvania.  On August 13, 2012, the Superior Court of Pennsylvania affirmed the award of past damages, but ruled that the lower court should have calculated future damages as of the date of breach, and remanded the matter back to the lower court with instructions to recalculate that portion of the award. On November 19, 2012, Allegheny filed a Petition for Allowance of Appeal with the Supreme Court of Pennsylvania and Wolf Run and Hunter Ridge filed an Answer.  On July 2, 2013, the Supreme Court of Pennsylvania denied the Petition of Allowance.  As this action finalized the past damage award, Wolf Run paid $15.6 million for the past damage amount, including interest, to Allegheny in July 2013.  Testimony on the future damage award in the lower court concluded on May 19, 2014, and post-trial briefs are due August 8, 2014.

 

In addition, the Company is a party to numerous other claims and lawsuits with respect to various matters. As of June 30, 2014 and December 31, 2013, the Company had accrued $23.9 million and $30.4 million, respectively, for all legal matters, including $10.9 million and $11.7 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.

 

15.            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 their per-ton operating costs (defined as including all mining costs but excluding pass-through transportation expenses), 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 and its ADDCAR subsidiary, which the Company sold in the first quarter of 2014.

 

Operating segment results for the three and six months ended June 30, 2014 and 2013 are presented below. Results for the reportable segments include all direct costs of mining, including all depreciation, depletion and amortization related to the mining operations, even if the assets are not recorded at the operating segment level.  These reportable segments results do not reflect impairment charges, since those are not reflected in the operating income reviewed by management.  Corporate, Other and Eliminations includes these charges, as well as 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.  The operating segment results and capital expenditures reflect only those from continuing operations, and exclude the results of Canyon Fuel, since they are classified as discontinued operations in the condensed consolidated statements of operations for the three and six months ended June 30, 2013.  Because the condensed consolidated statement of cash flows includes cash flows from discontinued operations, capital expenditures from discontinued operations are included in “Corporate, Other and Eliminations” below.

 

The asset amounts below represent an allocation of assets consistent with the basis used for the Company’s incentive compensation plans. The amounts in Corporate, Other and Eliminations represent primarily corporate assets (cash, receivables,

 

17



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investments, plant, property and equipment) as well as unassigned coal reserves, above-market acquired sales contracts and other unassigned assets.

 

 

 

PRB

 

APP

 

Other
Operating
Segments

 

Corporate,
Other and
Eliminations

 

Consolidated

 

 

 

(in thousands)

 

Three Months Ended June 30, 2014

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

358,265

 

$

280,961

 

$

74,550

 

$

 

$

713,776

 

Income (loss) from operations

 

5,103

 

(18,274

)

14,955

 

(37,589

)

(35,805

)

Depreciation, depletion and amortization

 

41,036

 

51,232

 

9,583

 

613

 

102,464

 

Amortization of acquired sales contracts, net

 

(785

)

(2,477

)

23

 

 

(3,239

)

Capital expenditures

 

6,962

 

11,037

 

2,358

 

60,935

 

81,292

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended June 30, 2013

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

353,425

 

$

337,678

 

$

75,229

 

$

 

$

766,332

 

Income (loss) from operations

 

16,755

 

(5,220

)

12,924

 

(60,738

)

(36,279

)

Depreciation, depletion and amortization

 

42,147

 

56,006

 

11,057

 

1,875

 

111,085

 

Amortization of acquired sales contracts, net

 

(941

)

(2,812

)

1,544

 

 

(2,209

)

Capital expenditures

 

1,819

 

43,470

 

4,771

 

64,482

 

114,542

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30, 2014

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

716,872

 

$

560,098

 

172,777

 

$

 

$

1,449,747

 

Income (loss) from operations

 

204

 

(44,002

)

16,728

 

(81,857

)

(108,927

)

Depreciation, depletion and amortization

 

80,281

 

106,220

 

19,102

 

1,284

 

206,887

 

Amortization of acquired sales contracts, net

 

(1,574

)

(5,451

)

90

 

 

(6,935

)

Capital expenditures

 

9,056

 

19,193

 

4,159

 

63,338

 

95,746

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30, 2013

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

715,371

 

$

620,296

 

$

168,035

 

$

 

$

1,503,702

 

Income (loss) from operations

 

32,272

 

(32,336

)

20,308

 

(107,954

)

(87,710

)

Depreciation, depletion and amortization

 

84,374

 

111,337

 

22,361

 

3,206

 

221,278

 

Amortization of acquired sales contracts, net

 

(2,140

)

(5,284

)

2,405

 

 

(5,019

)

Capital expenditures

 

3,976

 

92,767

 

5,266

 

67,055

 

169,064

 

 

A reconciliation of segment income (loss) from operations to consolidated loss before income taxes follows:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

 

 

 

 

Loss from operations

 

$

(35,805

)

$

(36,279

)

$

(108,927

)

$

(87,710

)

Interest expense

 

(97,960

)

(94,756

)

(194,431

)

(189,830

)

Interest and investment income

 

2,036

 

1,216

 

3,879

 

4,052

 

Loss from continuing operations before income taxes

 

$

(131,729

)

$

(129,819

)

$

(299,479

)

$

(273,488

)

 

16. 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):

 

18



Table of Contents

 

Condensed Consolidating Statements of Operations

Three Months Ended June 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

713,776

 

$

 

$

 

$

713,776

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

3,547

 

619,470

 

 

(880

)

622,137

 

Depreciation, depletion and amortization

 

1,346

 

101,109

 

9

 

 

102,464

 

Amortization of acquired sales contracts, net

 

 

(3,239

)

 

 

(3,239

)

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

 

 

(2,992

)

 

 

(2,992

)

Asset impairment costs

 

1,512

 

 

 

 

1,512

 

Selling, general and administrative expenses

 

21,729

 

7,250

 

1,489

 

(537

)

29,931

 

Other operating income, net

 

(1,883

)

1,554

 

(1,320

)

1,417

 

(232

)

 

 

26,251

 

723,152

 

178

 

 

749,581

 

Loss from investment in subsidiaries

 

2,502

 

 

 

(2,502

)

 

Loss from operations

 

(23,749

)

(9,376

)

(178

)

(2,502

)

(35,805

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(116,084

)

(6,565

)

(1,092

)

25,781

 

(97,960

)

Interest and investment income

 

8,125

 

18,341

 

1,351

 

(25,781

)

2,036

 

 

 

(107,959

)

11,776

 

259

 

 

(95,924

)

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

(131,708

)

2,400

 

81

 

(2,502

)

(131,729

)

Benefit from income taxes

 

(34,848

)

 

(21

)

 

(34,869

)

Net loss

 

$

(96,860

)

$

2,400

 

$

102

 

$

(2,502

)

$

(96,860

)

Total comprehensive income (loss)

 

$

(98,437

)

$

1,647

 

$

102

 

$

(1,749

)

$

(98,437

)

 

19



Table of Contents

 

Condensed Consolidating Statements of Operations

Three Months Ended June 30, 2013

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

766,332

 

$

 

$

 

$

766,332

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

1,829

 

654,369

 

 

 

656,198

 

Depreciation, depletion and amortization

 

1,475

 

109,601

 

9

 

 

111,085

 

Amortization of acquired sales contracts, net

 

 

(2,209

)

 

 

(2,209

)

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

 

 

(9,008

)

 

 

(9,008

)

Asset impairment costs

 

20,482

 

 

 

 

20,482

 

Selling, general and administrative expenses

 

22,205

 

10,729

 

1,368

 

 

34,302

 

Other operating income, net

 

(1,101

)

(7,041

)

(97

)

 

(8,239

)

 

 

44,890

 

756,441

 

1,280

 

 

802,611

 

Income from investment in subsidiaries

 

26,961

 

 

 

(26,961

)

 

Income (loss) from operations

 

(17,929

)

9,891

 

(1,280

)

(26,961

)

(36,279

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(110,946

)

(5,825

)

(1,059

)

23,074

 

(94,756

)

Interest and investment income

 

7,201

 

15,566

 

1,523

 

(23,074

)

1,216

 

 

 

(103,745

)

9,741

 

464

 

 

(93,540

)

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

(121,674

)

19,632

 

(816

)

(26,961

)

(129,819

)

Benefit from income taxes

 

(49,468

)

 

 

 

(49,468

)

Income (loss) from continuing operations

 

(72,206

)

19,632

 

(816

)

(26,961

)

(80,351

)

Income from discontinued operations, net of tax

 

 

8,145

 

 

 

8,145

 

Net income (loss)

 

$

(72,206

)

$

27,777

 

$

(816

)

$

(26,961

)

$

(72,206

)

Total comprehensive income (loss)

 

$

(68,163

)

$

28,123

 

$

(816

)

$

(27,307

)

$

(68,163

)

 

20



Table of Contents

 

Condensed Consolidating Statements of Operations

Six Months Ended June 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

1,449,747

 

$

 

$

 

$

1,449,747

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

6,937

 

1,303,246

 

 

(1,732

)

1,308,451

 

Depreciation, depletion and amortization

 

2,818

 

204,051

 

18

 

 

206,887

 

Amortization of acquired sales contracts, net

 

 

(6,935

)

 

 

(6,935

)

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

 

 

(2,078

)

 

 

(2,078

)

Asset impairment costs

 

1,512

 

 

 

 

1,512

 

Selling, general and administrative expenses

 

41,673

 

15,115

 

3,292

 

(1,013

)

59,067

 

Other operating income, net

 

(290

)

(7,929

)

(2,756

)

2,745

 

(8,230

)

 

 

52,650

 

1,505,470

 

554

 

 

1,558,674

 

Loss from investment in subsidiaries

 

(32,844

)

 

 

32,844

 

 

Loss from operations

 

(85,494

)

(55,723

)

(554

)

32,844

 

(108,927

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(229,739

)

(12,890

)

(2,142

)

50,340

 

(194,431

)

Interest and investment income

 

15,726

 

35,993

 

2,500

 

(50,340

)

3,879

 

 

 

(214,013

)

23,103

 

358

 

 

(190,552

)

 

 

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations before income taxes

 

(299,507

)

(32,620

)

(196

)

32,844

 

(299,479

)

Provision for (benefit from) income taxes

 

(78,508

)

 

28

 

 

(78,480

)

Net loss

 

$

(220,999

)

$

(32,620

)

$

(224

)

$

32,844

 

$

(220,999

)

Total comprehensive loss

 

$

(225,206

)

$

(34,779

)

$

(224

)

$

35,003

 

$

(225,206

)

 

21



Table of Contents

 

Condensed Consolidating Statements of Operations

Six Months Ended June 30, 2013

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-
Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Revenues

 

$

 

$

1,503,702

 

$

 

$

 

$

1,503,702

 

Costs, expenses and other

 

 

 

 

 

 

 

 

 

 

 

Cost of sales (exclusive of items shown separately below)

 

4,712

 

1,301,229

 

 

 

1,305,941

 

Depreciation, depletion and amortization

 

2,880

 

218,380

 

18

 

 

221,278

 

Amortization of acquired sales contracts, net

 

 

(5,019

)

 

 

(5,019

)

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

 

 

(7,700

)

 

 

(7,700

)

Asset impairment costs

 

20,482

 

 

 

 

20,482

 

Selling, general and administrative expenses

 

43,903

 

20,763

 

2,845

 

 

67,511

 

Other operating income, net

 

(7,009

)

(2,963

)

(1,109

)

 

(11,081

)

 

 

64,968

 

1,524,690

 

1,754

 

 

1,591,412

 

Income from investment in subsidiaries

 

19,492

 

 

 

(19,492

)

 

Income (loss) from operations

 

(45,476

)

(20,988

)

(1,754

)

(19,492

)

(87,710

)

Interest expense, net

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(221,761

)

(12,130

)

(2,100

)

46,161

 

(189,830

)

Interest and investment income

 

16,161

 

30,998

 

3,054

 

(46,161

)

4,052

 

 

 

(205,600

)

18,868

 

954

 

 

(185,778

)

 

 

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations before income taxes

 

(251,076

)

(2,120

)

(800

)

(19,492

)

(273,488

)

Benefit from income taxes

 

(108,821

)

 

 

 

(108,821

)

Loss from continuing operations

 

(142,255

)

(2,120

)

(800

)

(19,492

)

(164,667

)

Income from discontinued operations, net of tax

 

 

22,412

 

 

 

22,412

 

Net income (loss)

 

$

(142,255

)

$

20,292

 

$

(800

)

$

(19,492

)

$

(142,255

)

Total comprehensive income (loss)

 

$

(136,721

)

$

20,202

 

$

(800

)

$

(19,402

)

$

(136,721

)

 

22



Table of Contents

 

Condensed Consolidating Balance Sheets

June 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

628,251

 

$

100,360

 

$

11,543

 

$

 

$

740,154

 

Short term investments

 

248,647

 

 

 

 

248,647

 

Receivables

 

26,284

 

14,060

 

203,416

 

(4,609

)

239,151

 

Inventories

 

 

228,726

 

 

 

228,726

 

Other

 

85,461

 

38,039

 

1,610

 

 

125,110

 

Total current assets

 

988,643

 

381,185

 

216,569

 

(4,609

)

1,581,788

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, plant and equipment, net

 

16,663

 

6,586,776

 

19

 

 

6,603,458

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment in subsidiaries

 

7,643,340

 

 

 

(7,643,340

)

 

Intercompany receivables

 

 

2,009,804

 

 

(2,009,804

)

 

Note receivable from Arch Western

 

675,000

 

 

 

(675,000

)

 

Other

 

152,974

 

317,772

 

116

 

 

470,862

 

Total other assets

 

8,471,314

 

2,327,576

 

116

 

(10,328,144

)

470,862

 

Total assets

 

$

9,476,620

 

$

9,295,537

 

$

216,704

 

$

(10,332,753

)

$

8,656,108

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

 

 

 

 

Accounts payable

 

$

13,286

 

$

146,871

 

$

52

 

$

 

$

160,209

 

Accrued expenses and other current liabilities

 

70,523

 

227,552

 

851

 

(4,609

)

294,317

 

Current maturities of debt

 

22,011

 

5,255

 

 

 

27,266

 

Total current liabilities

 

105,820

 

379,678

 

903

 

(4,609

)

481,792

 

Long-term debt

 

5,092,064

 

24,289

 

 

 

5,116,353

 

Intercompany payables

 

1,820,942

 

 

188,862

 

(2,009,804

)

 

Note payable to Arch Coal

 

 

675,000

 

 

(675,000

)

 

Asset retirement obligations

 

1,037

 

394,776

 

 

 

395,813

 

Accrued pension benefits

 

2,869

 

11,056

 

 

 

13,925

 

Accrued postretirement benefits other than pension

 

4,374

 

33,660

 

 

 

38,034

 

Accrued workers’ compensation

 

27,214

 

46,869

 

 

 

74,083

 

Deferred income taxes

 

332,207

 

 

 

 

332,207

 

Other noncurrent liabilities

 

58,704

 

113,525

 

283

 

 

172,512

 

Total liabilities

 

7,445,231

 

1,678,853

 

190,048

 

(2,689,413

)

6,624,719

 

Stockholders’ equity

 

2,031,389

 

7,616,684

 

26,656

 

(7,643,340

)

2,031,389

 

Total liabilities and stockholders’ equity

 

$

9,476,620

 

$

9,295,537

 

$

216,704

 

$

(10,332,753

)

$

8,656,108

 

 

23



Table of Contents

 

Condensed Consolidating Balance Sheets

December 31, 2013

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

799,333

 

$

100,418

 

$

11,348

 

$

 

$

911,099

 

Short term investments

 

248,414

 

 

 

 

248,414

 

Receivables

 

14,177

 

23,018

 

197,015

 

(4,637

)

229,573

 

Inventories

 

 

264,161

 

 

 

264,161

 

Other

 

84,401

 

43,617

 

806

 

 

128,824

 

Total current assets

 

1,146,325

 

431,214

 

209,169

 

(4,637

)

1,782,071

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, plant and equipment, net

 

24,851

 

6,709,398

 

37

 

 

6,734,286

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment in subsidiaries

 

7,709,201

 

 

 

(7,709,201

)

 

Intercompany receivables

 

 

1,921,331

 

 

(1,921,331

)

 

Note receivable from Arch Western

 

675,000

 

 

 

(675,000

)

 

Other

 

162,287

 

311,463

 

86

 

 

473,836

 

Total other assets

 

8,546,488

 

2,232,794

 

86

 

(10,305,532

)

473,836

 

Total assets

 

$

9,717,664

 

$

9,373,406

 

$

209,292

 

$

(10,310,169

)

$

8,990,193

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

 

 

 

 

Accounts payable

 

$

17,781

 

$

158,224

 

$

137

 

$

 

$

176,142

 

Accrued expenses and other current liabilities

 

53,779

 

228,664

 

781

 

(4,637

)

278,587

 

Current maturities of debt

 

28,882

 

4,611

 

 

 

33,493

 

Total current liabilities

 

100,442

 

391,499

 

918

 

(4,637

)

488,222

 

Long-term debt

 

5,099,833

 

18,169

 

 

 

5,118,002

 

Intercompany payables

 

1,740,236

 

 

181,095

 

(1,921,331

)

 

Note payable to Arch Coal

 

 

675,000

 

 

(675,000

)

 

Asset retirement obligations

 

1,095

 

401,618

 

 

 

402,713

 

Accrued pension benefits

 

7,797

 

(686

)

 

 

7,111

 

Accrued postretirement benefits other than pension

 

12,079

 

27,176

 

 

 

39,255

 

Accrued workers’ compensation

 

21,546

 

56,516

 

 

 

78,062

 

Deferred income taxes

 

413,546

 

 

 

 

413,546

 

Other noncurrent liabilities

 

67,841

 

121,794

 

398

 

 

190,033

 

Total liabilities

 

7,464,415

 

1,691,086

 

182,411

 

(2,600,968

)

6,736,944

 

Stockholders’ equity

 

2,253,249

 

7,682,320

 

26,881

 

(7,709,201

)

2,253,249

 

Total liabilities and stockholders’ equity

 

$

9,717,664

 

$

9,373,406

 

$

209,292

 

$

(10,310,169

)

$

8,990,193

 

 

24



Table of Contents

 

Condensed Consolidating Statements of Cash Flows

Six Months Ended June 30, 2014

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Cash provided by (used in) operating activities

 

$

(268,382

)

$

196,505

 

$

(6,469

)

$

 

$

(78,346

)

Investing Activities

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

(660

)

(95,086

)

 

 

(95,746

)

Payments of minimum royalties

 

 

(3,341

)

 

 

(3,341

)

Proceeds from disposals and divestitures

 

39,132

 

4,113

 

 

 

43,245

 

Purchases of short term investments

 

(168,951

)

 

 

 

(168,951

)

Proceeds from sales of short term investments

 

166,018

 

 

 

 

 

166,018

 

Investments in and advances to affiliates

 

(1,581

)

(7,920

)

 

 

(9,501

)

Cash provided by (used in) investing activities

 

33,958

 

(102,234

)

 

 

(68,276

)

Financing Activities

 

 

 

 

 

 

 

 

 

 

 

Payments on term loan

 

(9,750

)

 

 

 

(9,750

)

Net payments on other debt

 

(7,547

)

(1,843

)

 

 

(9,390

)

Debt financing costs

 

(1,957

)

 

 

 

(1,957

)

Dividends paid

 

(2,123

)

 

 

 

(2,123

)

Change in restricted cash

 

 

 

(1,103

)

 

(1,103

)

Transactions with affiliates, net

 

84,719

 

(92,486

)

7,767

 

 

 

Cash provided by (used in) financing activities

 

63,342

 

(94,329

)

6,664

 

 

(24,323

)

Increase (decrease) in cash and cash equivalents

 

(171,082

)

(58

)

195

 

 

(170,945

)

Cash and cash equivalents, beginning of period

 

799,333

 

100,418

 

11,348

 

 

911,099

 

Cash and cash equivalents, end of period

 

$

628,251

 

$

100,360

 

$

11,543

 

$

 

$

740,154

 

 

25



Table of Contents

 

Condensed Consolidating Statements of Cash Flows

Six Months Ended June 30, 2013

 

 

 

Parent/Issuer

 

Guarantor
Subsidiaries

 

Non-Guarantor
Subsidiaries

 

Eliminations

 

Consolidated

 

 

 

(In thousands)

 

Cash provided by (used in) operating activities

 

$

(217,517

)

$

287,055

 

$

(17,493

)

$

 

$

52,045

 

Investing Activities

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

(1,511

)

(167,553

)

 

 

(169,064

)

Payments of minimum royalties

 

 

(10,162

)

 

 

(10,162

)

Proceeds from sale-leaseback transactions

 

 

5,080

 

 

 

5,080

 

Proceeds from disposals and divestitures

 

 

34,919

 

 

 

34,919

 

Purchases of short term investments

 

(61,870

)

 

 

 

(61,870

)

Proceeds from sales of short term investments

 

47,097

 

 

 

 

47,097

 

Investments in and advances to affiliates

 

(3,012

)

(5,385

)

 

255

 

(8,142

)

Change in restricted cash

 

2,368

 

 

 

 

2,368

 

Cash provided by (used in) investing activities

 

(16,928

)

(143,101

)

 

255

 

(159,774

)

Financing Activities

 

 

 

 

 

 

 

 

 

 

 

Contributions from parent

 

 

255

 

 

(255

)

 

Payments on term loan

 

(8,250

)

 

 

 

(8,250

)

Net payments on other debt

 

(11,448

)

(255

)

 

 

(11,703

)

Dividends paid

 

(12,735

)

 

 

 

(12,735

)

Transactions with affiliates, net

 

127,370

 

(143,975

)

16,605

 

 

 

Cash provided by (used in) financing activities

 

94,937

 

(143,975

)

16,605

 

(255

)

(32,688

)

Decrease in cash and cash equivalents

 

(139,508

)

(21

)

(888

)

 

(140,417

)

Cash and cash equivalents, beginning of period

 

671,313

 

100,468

 

12,841

 

 

784,622

 

Cash and cash equivalents, end of period

 

$

531,805

 

$

100,447

 

$

11,953

 

$

 

$

644,205

 

 

26



Table of Contents

 

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

 

Overview

 

Our results during the second quarter of 2014, when compared to the second quarter of 2013, were impacted by the continuing weakness in coal markets, particularly for metallurgical coal, and rail issues in the Powder River Basin.

 

Seaborne coal markets remain challenged, as oversupply continues to pressure global prices for metallurgical and thermal coals, and we expect the seaborne markets to remain weak throughout 2014. We have limited our forward exposure to the export market at this time, but we are positioned to increase export shipments should fundamentals improve.

 

Due to the weak markets, we sold 1.7 million tons of metallurgical coal in the second quarter of 2014 compared to 2.1 million tons in the second quarter of 2013, and 3.3 million tons of metallurgical coal during the first half of 2014 compared to 3.8 million tons during the first half of 2013.

 

Power generation levels in the U.S. increased marginally for the first half of the year, benefiting from cold winter weather, offset by a milder to-date spring and summer.  Weather-related delays and rail service disruptions have impacted deliveries, particularly to plants sourced from the Powder River Basin.  But demand increased compared with the prior year, resulting in higher prices for new firm sales commitments in the Powder River Basin. At the same time, the lack of sustained summer heat, a slower-growing economy, and waning natural gas prices have recently been pressuring the Powder River Basin market.  See further information regarding committed sales in Item 3. Quantitative and Qualitative Disclosures About Market Risk.

 

In the face of weak coal markets, management has chosen to concentrate metallurgical coal production at our lowest-cost and highest-margin operations and announced the idling of a higher-cost mining complex in Appalachia in July 2014. We have retained the option to restart production should metallurgical coal markets strengthen.  In addition, we continue to focus on capital spending reductions, cost containment and efficiency efforts, and working capital and liquidity management to preserve liquidity and prepare the company to capitalize on opportunities when coal markets recover.

 

Regional Performance

 

The following table shows results by operating segment for the three and six months ended June 30, 2014 and compares it with the information for the three and six months ended June 30, 2013.  The “other” category represents 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 June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

Powder River Basin

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

26,928

 

27,131

 

52,594

 

53,743

 

Coal sales per ton sold

 

$

12.79

 

$

12.56

 

$

12.76

 

$

12.62

 

Cost per ton sold

 

$

12.61

 

$

12.02

 

$

12.80

 

$

12.13

 

Operating margin (loss) per ton sold

 

$

0.18

 

$

0.54

 

$

(0.04

)

$

0.49

 

Adjusted EBITDA (in thousands)

 

$

45,354

 

$

57,961

 

$

78,912

 

$

114,505

 

Appalachia

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

3,687

 

4,042

 

7,276

 

7,429

 

Coal sales per ton sold

 

$

69.36

 

$

74.18

 

$

68.54

 

$

74.44

 

Cost per ton sold

 

$

76.25

 

$

79.56

 

$

78.49

 

$

81.35

 

Operating loss per ton sold

 

$

(6.89

)

$

(5.38

)

$

(9.95

)

$

(6.91

)

Adjusted EBITDA (in thousands)

 

$

30,481

 

$

47,974

 

$

56,767

 

$

73,716

 

Other

 

 

 

 

 

 

 

 

 

Tons sold (in thousands)

 

2,048

 

1,780

 

4,150

 

3,706

 

Coal sales per ton sold

 

$

31.34

 

$

35.69

 

$

29.97

 

$

33.97

 

Cost per ton sold

 

$

24.51

 

$

28.40

 

$

25.85

 

28.79

 

Operating margin per ton sold

 

$

6.83

 

$

7.29

 

$

4.12

 

$

5.18

 

Adjusted EBITDA (in thousands)

 

$

24,561

 

$

24,490

 

$

37,756

 

$

44,115

 

 

27



Table of Contents

 

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 decreased 22% in the second quarter and 31% in the first half of 2014 when compared to the respective periods in 2013 due to lower shipment volumes and higher costs, primarily repairs and maintenance spending.  These costs were incurred in anticipation of higher shipment volume levels to meet expected higher demand in the region; however, ongoing rail performance issues have impacted shipments out of the region.  Pricing has improved in the region, which partially offset the impact of the lower shipment levels.

 

Appalachia — Adjusted EBITDA decreased in the second quarter and first half of 2014 when compared to the respective periods in 2013, due primarily to the weak metallurgical coal markets, which resulted in a decrease in metallurgical coal sales volumes and lower average coal pricing.  Thermal coal sales volumes, however, increased in the first half of 2014 when compared to 2013  levels.  Thermal coal pricing was lower in the first half of 2014 than in the prior year. The startup of the longwall at the low-cost Leer mining complex, lower depreciation, depletion and amortization costs, and lower sales-sensitive costs contributed to lower per-ton costs in the second quarter and first half of 2014 when compared to the respective periods in 2013.  The shift of production to the Leer mining complex offset the impact of longwall geological issues elsewhere in the region, which should improve in the third quarter of 2014.  Adjusted EBITDA in the first half of 2014 also benefited from the sale of a thermal coal complex and idled thermal coal mine in Kentucky in the first quarter ($15.6 million).  See Note 4 to the condensed consolidated financial statement for further discussion.

 

Other — Operating margin per ton and Adjusted EBITDA were impacted by lower average per-ton pricing in the second quarter and the first half of 2014 when compared to the respective periods in 2013 due to a decrease in export pricing and the roll-off of long-term contracts, which resulted in a decrease in per-ton realizations.  Lower per-ton pricing was partially offset by an improvement in per-ton costs, the result of higher sales volumes and cost control efforts.

 

Results of Operations

 

Three Months Ended June 30, 2014 Compared to Three Months Ended June 30, 2013

 

Revenues.  Our revenues consist of coal sales and revenues from our ADDCAR subsidiary prior to its disposition in the first quarter of 2014.

 

Coal sales.  The following table summarizes information about our coal sales during the three months ended June 30, 2014 and compares it with the information for the three months ended June 30, 2013:

 

 

 

Three Months Ended June 30,

 

 

 

 

 

2014

 

2013

 

Decrease

 

 

 

(In thousands)

 

Coal sales

 

$

713,776

 

$

761,604

 

$

(47,828

)

Tons sold

 

32,663

 

32,953

 

(290

)

 

On a consolidated basis, coal sales decreased in the second quarter of 2014 from the second quarter of 2013, due to the impact of lower sales volumes (a decrease of approximately $6 million) and the impact of lower average per-ton pricing (a decrease of approximately $42 million).  Average pricing decreased from $23.11 to $21.85 per ton due mainly to declines in metallurgical coal sales and the impact of changes in the regional mix, as sales volumes decreased in regions with higher pricing.  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 June 30, 2014 and compares it with the information for the three months ended June 30, 2013:

 

28



Table of Contents

 

 

 

Three Months Ended June 30,

 

(Increase) Decrease

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Cost of sales (exclusive of items shown separately below)

 

$

622,137

 

$

656,198

 

$

34,061

 

Depreciation, depletion and amortization

 

102,464

 

111,085

 

8,621

 

Amortization of acquired sales contracts, net

 

(3,239

)

(2,209

)

1,030

 

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

 

(2,992

)

(9,008

)

(6,016

)

Asset impairment costs

 

1,512

 

20,482

 

18,970

 

Selling, general and administrative expenses

 

29,931

 

34,302

 

4,371

 

Other operating income, net

 

(232

)

(8,239

)

(8,007

)

Total costs, expenses and other

 

$

749,581

 

$

802,611

 

$

53,030

 

 

Cost of sales.  Our cost of sales decreased in the second quarter of 2014 from the second quarter of 2013, due to lower sales volumes (a decrease of approximately $5 million) and average per-ton costs (a decrease of approximately $13 million).  Lower average per-ton costs were the result of a decrease in sales volumes from higher-cost regions.  See discussion in “Regional Performance” for further information about regional results. In addition, the disposition of ADDCAR in the first quarter of 2014 resulted in a decrease of $3.7 million in cost of sales.  Transportation costs decreased approximately $13 million in the second quarter of 2014 from the second quarter of 2013, primarily due to decreased export shipments.

 

Depreciation, depletion and amortization.  When compared with the second quarter of 2013, depreciation, depletion and amortization costs decreased in 2014 primarily due to mine idlings and dispositions in Appalachia and lower production and capital spending levels in other regions.

 

Asset Impairment costs.  In the second quarter of 2013, we impaired an investment in a clean coal power plant project and a related receivable balance.

 

Selling, general and administrative expenses.  Total selling, general and administrative expenses decreased when compared with the second quarter of 2013, due to decreases in legal and professional fees ($2.3 million), salary and benefit related costs ($1.7 million), and other decreases in discretionary spending.

 

Other operating income, net.  When compared with the second quarter of 2013, other operating income, net decreased during the second quarter of 2014, primarily due to costs of $10.4 million in the second quarter of 2014 related to export shortfalls under throughput arrangements (an increase of $8.8 million from the second quarter of 2013) and a decrease in settlement gains of $5.3 million on derivatives used to manage coal price risk. These were partially offset by a decrease in unrealized losses on derivatives in our diesel purchase risk management of $5.2 million and an increase in gains on asset sales of $1.2 million.

 

Benefit from income taxes.  The following table summarizes our benefit from income taxes for the three months ended June 30, 2014 and compares it with the information for the three months ended June 30, 2013:

 

 

 

Three Months Ended June 30,

 

Increase

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Benefit from income taxes

 

$

(34,869

)

$

(49,468

)

$

(14,599

)

 

The income tax benefit rate of 26% in the second quarter of 2014 decreased from 38% in the second quarter of 2013 due to the establishment of a valuation allowance totaling approximately $18 million relating to 2014 federal and state net operating loss carryforwards.  See further discussion in Note 10 to the condensed consolidated financial statements.

 

Income from discontinued operations, net of tax The results of our Canyon Fuel subsidiary prior to its disposal are segregated from continuing operations. See further information in Note 4 to the condensed consolidated financial statements.

 

29



Table of Contents

 

 

 

Three Months Ended June 30,

 

Increase

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Income from discontinued operations, net of tax

 

$

 

$

8,145

 

$

(8,145

)

 

Six Months Ended June 30, 2014 Compared to Six Months Ended June 30, 2013

 

Revenues.  Our revenues consist of coal sales and revenues from our ADDCAR subsidiary prior to its disposition in the first quarter of 2014.

 

Coal sales.  The following table summarizes information about our coal sales during the six months ended June 30, 2014 and compares it with the information for the six months ended June 30, 2013:

 

 

 

Six Months Ended June 30,

 

 

 

 

 

2014

 

2013

 

Decrease

 

 

 

(In thousands)

 

Coal sales

 

$

1,447,809

 

$

1,498,090

 

$

(50,281

)

Tons sold

 

64,020

 

64,878

 

(858

)

 

Coal sales decreased slightly in the first half of 2014 from the first half of 2013 on a consolidated basis, primarily due to the impact of lower sales volumes (a decrease of approximately $19 million) and the impact of lower average per-ton pricing (a decrease of approximately $31 million).  Average pricing decreased from $23.09 to $22.61 per ton, primarily due to declines in metallurgical coal sales, partially offset by improvements in Powder River Basin pricing.  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 six months ended June 30, 2014 and compares it with the information for the six months ended June 30, 2013:

 

 

 

Six Months Ended June 30,

 

(Increase) Decrease

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Cost of sales (exclusive of items shown separately below)

 

$

1,308,451

 

$

1,305,941

 

$

(2,510

)

Depreciation, depletion and amortization

 

206,887

 

221,278

 

14,391

 

Amortization of acquired sales contracts, net

 

(6,935

)

(5,019

)

1,916

 

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

 

(2,078

)

(7,700

)

(5,622

)

Asset impairment costs

 

1,512

 

20,482

 

18,970

 

Selling, general and administrative expenses

 

59,067

 

67,511

 

8,444

 

Other operating income, net

 

(8,230

)

(11,081

)

(2,851

)

Total costs, expenses and other

 

$

1,558,674

 

$

1,591,412

 

$

32,738

 

 

Cost of sales.  Our cost of sales remained flat in the first half of 2014 from the first half of 2013, as the impact of lower sales volumes were offset by higher average per-ton costs.  Higher average per-ton costs resulted in an increase in cost of sales of approximately $16 million. See discussion in “Regional Performance” for further information about regional cost results.

 

Depreciation, depletion and amortization.  When compared with the first half of 2013, depreciation, depletion and amortization costs decreased in 2014 primarily due to mine idlings and dispositions in Appalachia and lower production and capital spending levels in other regions.

 

Asset impairment costs. Please see the discussion in comparison of results for the three months periods ended June30, 2014 and 2013.

 

30



Table of Contents

 

Selling, general and administrative expenses.  Total selling, general and administrative expenses decreased when compared with the first half of 2013, due generally to decreases in legal and professional fees ($4.3 million), salary and benefit related costs ($4.0 million), and other decreases in discretionary spending.

 

Other operating income, net.  When compared with the first half of 2013, other operating income, net decreased during the first half of 2014, primarily as a result of costs of $22.9 million in the first half of 2014 related to export shortfalls under throughput arrangements (an increase of $10.9 million from the first half of 2013), a decrease in realized gains of $11.6 million on derivatives used to manage coal price risk, and a decrease in contract settlement gains of $4.1 million.  These were offset by the an increase in gains on asset disposals of $15.7 million, primarily from the divestitures of mining operations in the Appalachia region and our ADDCAR subsidiary in the first quarter of 2014, and a decrease in unrealized losses of $6.8 million on derivatives used in our diesel purchase risk management program.

 

Benefit from income taxes.  The following table summarizes our benefit from income taxes for the six months ended June 30, 2014 and compares it with the information for the six months ended June 30, 2013:

 

 

 

Six Months Ended June 30,

 

Increase

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Benefit from income taxes

 

$

(78,480

)

$

(108,821

)

$

(30,341

)

 

The income tax benefit rate of 26% in the first half of 2014 decreased from 40% in the first half of 2013 due to the establishment of a valuation allowance totaling approximately $42 million relating to 2014 federal and state net operating loss carryforwards.  See further discussion in Note 10 to the condensed consolidated financial statements.

 

Income from discontinued operations, net of tax The results of our Canyon Fuel subsidiary prior to its disposal are segregated from continuing operations. See further information in Note 4 to the condensed consolidated financial statements.

 

 

 

Six Months Ended June 30,

 

Increase

 

 

 

2014

 

2013

 

in Net Loss

 

 

 

(In thousands)

 

Income from discontinued operations, net of tax

 

$

 

$

22,412

 

$

(22,412

)

 

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 income” 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.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Reported segment coal sales revenues

 

$

664,481

 

$

704,215

 

$

1,294,434

 

$

1,357,102

 

Coal risk management derivative settlements classified in “other income”

 

(1,318

)

(6,579

)

(4,197

)

(15,796

)

Transportation costs

 

50,613

 

63,968

 

157,573

 

156,784

 

Coal sales

 

$

713,776

 

$

761,604

 

$

1,447,810

 

$

1,498,090

 

 

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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” 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 June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

 

 

 

 

 

 

 

 

 

 

Reported segment cost of tons sold

 

$

671,130

 

$

698,440

 

$

1,351,427

 

$

1,363,116

 

Diesel fuel risk management derivative settlements classified in “other income”

 

(1,684

)

(3,584

)

(3,563

)

(8,246

)

Transportation costs

 

50,613

 

63,968

 

157,573

 

156,784

 

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

 

(101,851

)

(108,780

)

(205,603

)

(217,215

)

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

 

3,929

 

6,154

 

8,617

 

11,502

 

Cost of sales

 

$

622,137

 

$

656,198

 

$

1,308,451

 

$

1,305,941

 

 

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.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(In thousands)

 

Reported Segment Adjusted EBITDA

 

$

100,396

 

$

130,425

 

$

173,435

 

$

232,336

 

EBITDA from discontinued operations

 

 

17,471

 

 

45,148

 

Corporate and other (1)

 

(35,464

)

(37,346

)

(80,898

)

(83,305

)

Adjusted EBITDA

 

64,932

 

110,550

 

92,537

 

194,179

 

Income tax benefit

 

34,869

 

49,468

 

78,480

 

108,821

 

Interest expense, net

 

(95,924

)

(93,540

)

(190,552

)

(185,778

)

Depreciation, depletion and amortization

 

(102,464

)

(111,085

)

(206,887

)

(221,278

)

Amortization of acquired sales contracts, net

 

3,239

 

2,209

 

6,935

 

5,019

 

Asset impairment costs

 

(1,512

)

(20,482

)

(1,512

)

(20,482

)

Interest, depreciation, depletion and amortization classified as discontinued operations

 

 

(9,326

)

 

(22,736

)

Net loss

 

$

(96,860

)

$

(72,206

)

$

(220,999

)

$

(142,255

)

 


(1)              Corporate and other includes primarily selling, general and administrative expenses, certain asset impairments, income from our equity investments and certain changes in the fair value of coal derivatives and coal trading activities.

 

Liquidity and Capital Resources

 

Our primary sources of cash are coal sales to customers, availability under our credit facilities and other financing arrangements, and debt and equity offerings related to significant transactions or refinancing activity. Excluding significant investing activity, we generally satisfy our working capital requirements and fund capital expenditures and debt-service obligations with cash generated from operations, cash on hand or borrowings under our lines of credit. Such 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.

 

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We have no meaningful maturities of debt until 2018, and we have suspended or eliminated most financial maintenance covenants that pertain only to our $250 million revolver until June of 2015, when a relaxed, senior secured leverage ratio covenant becomes effective. Until then, only a minimum liquidity covenant of $550 million remains in place.  We had liquidity of nearly $1.25 billion at June 30, 2014, with $989 million of that in cash and liquid securities.  We have no borrowings outstanding under our revolving credit agreement at June 30, 2014.

 

The following is a summary of cash provided by or used in each of the indicated types of activities during the six months ended June 30, 2014 and 2013:

 

 

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(In thousands)

 

Cash provided by (used in):

 

 

 

 

 

Operating activities

 

$

(78,346

)

$

52,045

 

Investing activities

 

(68,276

)

(159,774

)

Financing activities

 

(24,323

)

(32,688

)

 

We used cash in operating activities during the first half of 2014 compared to generating cash from operations in the first half of 2013, driven by the decrease in our operating profitability resulting from weak coal market conditions and shipping issues in the Powder River Basin.

 

We used $91.5 million less cash in investing activities during the first half of 2014 compared to the first half of 2013.  Capital expenditures and additions to prepaid royalties decreased approximately $73.3 million and $6.8 million, respectively, during the first half of 2014 when compared to the first half of 2013.  Cash conservation efforts and the start up of the Leer mining complex longwall in the first quarter of 2014 were responsible for the decrease in capital expenditures.  The divestitures of a Kentucky operation and idled assets and our ADDCAR subsidiary contributed to an increase of $8.3 million in proceeds from asset sales and divestitures over the first half of 2013.  We will receive additional consideration of $11 million by the end of 2014 relating to the ADDCAR divestiture.  Compared with the six months ended June 30, 2013, we invested net $11.8 million less in short term investments in the six months ended June 30, 2014.

 

Cash used in financing activities was approximately $8 million less in the six months ended June 30, 2014, primarily due to the decrease in the dividend rate.  The decrease in the dividend rate in the first quarter of 2014 from $0.03 per quarter to $0.01 per annum reduced dividends paid from $12.7 million during the six months ended June 30, 2013 to $2.1 million during the six months ended June 30, 2014.

 

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:

 

 

 

Six Months Ended June 30,

 

 

 

2014

 

2013

 

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 were $95.5 million and total fixed charges were $200.2 million for the six months ended June 30, 2014.  Total losses for the ratio calculation were $80.3 million and total fixed charges were $202.7 million for the six months ended June 30, 2013.

 

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Item 3.  Quantitative and Qualitative Disclosures About Market Risk.

 

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

 

Our sales commitments were as follows as of July 25, 2014:

 

 

 

2014

 

2015

 

 

 

Tons

 

$ per ton

 

Tons

 

$ per ton

 

 

 

(in millions)

 

 

 

(in millions)

 

 

 

Powder River Basin

 

 

 

 

 

 

 

 

 

Committed, Priced

 

109.8

 

$

13.00

 

74.9

 

$

13.72

 

Committed, Unpriced

 

3.6

 

 

 

9.7

 

 

 

Appalachia

 

 

 

 

 

 

 

 

 

Committed, Priced Thermal

 

7.3

 

$

57.72

 

3.4

 

$

56.71

 

Committed, Unpriced Thermal

 

0.2

 

 

 

 

 

 

Committed, Priced Metallurgical

 

6.0

 

$

82.44

 

1.6

 

$

85.53

 

Committed, Unpriced Metallurgical

 

0.2

 

 

 

0.3

 

 

 

Other Bituminous

 

 

 

 

 

 

 

 

 

Committed, Priced

 

7.6

 

$

31.00

 

3.3

 

$

36.32

 

Committed, Unpriced

 

0.2

 

 

 

 

 

 

 

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 June 30, 2014. The estimated future realization of the value of the trading portfolio is $6.3 million of gains in the remainder of 2014 and $2.9 million of gains in 2015.

 

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

 

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

 

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

 

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

 

During the six months ended June 30, 2014, 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 $0.3 million. The final VaR at June 30, 2014 was $0.4 million.

 

We are exposed to fluctuations in the fair value of coal derivatives that we enter into to manage the price risk related to future coal sales, but for which we do not elect hedge accounting. Gains or losses on these derivative instruments would be largely offset in the pricing of the physical coal sale.  During the six months ended June 30, 2014 VaR for our risk management positions that are recorded at fair value through earnings ranged from $0.1 million to $0.5 million. The linear mean of each daily VaR was $0.3 million. The final VaR at June 30, 2014 was $0.2 million.

 

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We are also exposed to the risk of fluctuations in cash flows related to our purchase of diesel fuel. We expect to use approximately 57 to 67 million gallons of diesel fuel for use in our operations during 2014. 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 June 30, 2014, we had protected the price of approximately 88% of our expected purchases for the remainder of 2014 and 80% of our 2015 purchases through the third quarter.  At June 30, 2014, we had purchased heating oil call options for approximately 70 million gallons for the purpose of managing the price risk associated with future diesel purchases. We also purchase heating oil call options to manage the price risk associated with fuel surcharges on barge and rail shipments, which cover increases in diesel fuel prices.  At June 30, 2014, we held purchased call options for approximately 3.4 million gallons for the purpose of managing the fluctuations in cash flows associated with fuel surcharges on future shipments.  These positions reduce our risk of cash flow fluctuations related to these surcharges but the positions are not accounted for as hedges.  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 June 30, 2014, 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 June 30, 2014, 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 June 30, 2014.  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.

 

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 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.

 

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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.

 

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

 

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Table of Contents

 

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.

 

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.  The matter has been remanded to the federal district court for the District of Columbia where it is pending further proceedings on the merits of the Final Determination.

 

Allegheny Energy Contract Matter

 

Allegheny Energy Supply (“Allegheny”), the sole customer of coal produced at our subsidiary Wolf Run Mining Company’s (“Wolf Run”) Sycamore No. 2 mine, filed a lawsuit against Wolf Run, Hunter Ridge Holdings, Inc. (“Hunter Ridge”), and ICG in state court in Allegheny County, Pennsylvania on December 28, 2006, and amended its complaint on April 23, 2007. Allegheny claimed that Wolf Run breached a coal supply contract when it declared force majeure under the contract upon idling the Sycamore No. 2 mine in the third quarter of 2006, and that Wolf Run continued to breach the contract by failing to ship in volumes referenced in the contract.  The Sycamore No. 2 mine was idled after encountering adverse geologic conditions and abandoned gas wells that were previously unidentified and unmapped.

 

After extensive searching for gas wells and rehabilitation of the mine, it was re-opened in 2007, but with notice to Allegheny that it would necessarily operate at reduced volumes in order to safely and effectively avoid the many gas wells within the reserve.  The amended complaint also alleged that the production stoppages constitute a breach of the guarantee agreement by Hunter Ridge and breach of certain representations made upon entering into the contract in early 2005.  Allegheny voluntarily dropped the breach of representation claims later.  Allegheny claimed that it would incur costs in excess of $100 million to purchase replacement coal over the life of the contract.  ICG, Wolf Run and Hunter Ridge answered the amended complaint on August 13, 2007, disputing all of the remaining claims.

 

On November 3, 2008, ICG, Wolf Run and Hunter Ridge filed an amended answer and counterclaim against the plaintiffs seeking to void the coal supply agreement due to, among other things, fraudulent inducement and conspiracy.  On September 23, 2009, Allegheny filed a second amended complaint alleging several alternative theories of liability in its effort to extend contractual liability to ICG, which was not a party to the original contract and did not exist at the time Wolf Run and

 

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Allegheny entered into the contract.  No new substantive claims were asserted.  ICG answered the second amended complaint on October 13, 2009, denying all of the new claims.  The Company’s counterclaim was dismissed on motion for summary judgment entered on May 11, 2010.  Allegheny’s claims against ICG were also dismissed by summary judgment, but the claims against Wolf Run and Hunter Ridge were not.  The court conducted a non-jury trial of this matter beginning on January 10, 2011 and concluding on February 1, 2011.

 

At the trial, Allegheny presented its evidence for breach of contract and claimed that it is entitled to past and future damages in the aggregate of between $228 million and $377 million.  Wolf Run and Hunter Ridge presented their defense of the claims, including evidence with respect to the existence of force majeure conditions and excuse under the contract and applicable law.  Wolf Run and Hunter Ridge presented evidence that Allegheny’s damages calculations were significantly inflated because it did not seek to determine damages as of the time of the breach and in some instances artificially assumed future nondelivery or did not take into account the apparent requirement to supply coal in the future.  On May 2, 2011, the trial court entered a Memorandum and Verdict determining that Wolf Run had breached the coal supply contract and that the performance shortfall was not excused by force majeure.  The trial court awarded total damages and interest in the amount of $104.1 million, which consisted of $13.8 million for past damages, and $90.3 million for future damages.  ICG and Allegheny filed post-verdict motions in the trial court and on August 23, 2011, the court denied the parties’ motions.  The court entered a final judgment on August 25, 2011, in the amount of $104.1 million, which included pre-judgment interest.

 

The parties appealed the lower court’s decision to the Superior Court of Pennsylvania.  On August 13, 2012, the Superior Court of Pennsylvania affirmed the award of past damages, but ruled that the lower court should have calculated future damages as of the date of breach, and remanded the matter back to the lower court with instructions to recalculate that portion of the award. On November 19, 2012, Allegheny filed a Petition for Allowance of Appeal with the Supreme Court of Pennsylvania and Wolf Run and Hunter Ridge filed an Answer.  On July 2, 2013, the Supreme Court of Pennsylvania denied the Petition of Allowance.  As this action finalized the past damage award, Wolf Run paid $15.6 million for the past damage amount, including interest, to Allegheny in July 2013.  Testimony on the future damage award in the lower court concluded on May 19, 2014, and post-trial briefs are due August 8, 2014.

 

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 14,000,000 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 June 30, 2014, there were 10,925,800 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 June 30, 2014. Based on the closing price of our common stock as reported on the New York Stock Exchange on July 31, 2014, the approximate dollar value of our common stock that may yet be purchased under this program was $32.4 million.

 

Item 4.  Mine Safety Disclosures.

 

The statement concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 to this Quarterly Report on Form 10-Q for the period ended June 30, 2014.

 

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 six months ended June 30, 2014 filed in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed.”

 

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Table of Contents

 

Signatures

 

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

 

 

 

Arch Coal, Inc.

 

 

 

 

 

 

 

By:

/s/ John T. Drexler

 

 

John T. Drexler

 

 

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

 

 

 

 

 

August 8, 2014

 

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