-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, M8A1Ndff3uJYWoA9oj+kj4zMpIS0+IWF0M6COIxAbpa2f29BugAX/tbss9pXeuXP Icx4Qp6e9du19zNnR+LC/w== 0000037748-10-000042.txt : 20101108 0000037748-10-000042.hdr.sgml : 20101108 20101108171138 ACCESSION NUMBER: 0000037748-10-000042 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 12 CONFORMED PERIOD OF REPORT: 20100930 FILED AS OF DATE: 20101108 DATE AS OF CHANGE: 20101108 FILER: COMPANY DATA: COMPANY CONFORMED NAME: MASSEY ENERGY CO CENTRAL INDEX KEY: 0000037748 STANDARD INDUSTRIAL CLASSIFICATION: BITUMINOUS COAL & LIGNITE SURFACE MINING [1221] IRS NUMBER: 950740960 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-07775 FILM NUMBER: 101173249 BUSINESS ADDRESS: STREET 1: 4 NORTH 4TH STREET CITY: RICHMOND STATE: VA ZIP: 23219 BUSINESS PHONE: 9493492000 MAIL ADDRESS: STREET 1: 4 NORTH 4TH STREET CITY: RICHMOND STATE: VA ZIP: 23219 FORMER COMPANY: FORMER CONFORMED NAME: FLUOR CORP/DE/ DATE OF NAME CHANGE: 19920703 FORMER COMPANY: FORMER CONFORMED NAME: FLUOR CORP LTD DATE OF NAME CHANGE: 19710624 10-Q 1 form09301010q.htm FORM 10-Q form09301010q.htm
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 10-Q

 (Mark One)
x
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the quarterly period ended September 30, 2010

OR
 
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from                      to                     
 
Commission File No. 001-07775
 
MASSEY ENERGY COMPANY
(Exact name of registrant as specified in its charter)
 
   
Delaware
95-0740960
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification Number)
   
4 North 4th Street, Richmond, Virginia
23219
(Address of principal executive offices)
(Zip Code)
 
(804) 788-1800
(Registrant’s telephone number, including area code)
 
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 ¨

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 ¨

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 definition 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 ¨
   Non-accelerated filer ¨ (Do not check if a smaller reporting company)    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 ¨ No x

As of October 27, 2010, there were 102,124,340 shares of common stock, $0.625 par value (“Common Stock”), outstanding.
 
 
 

MASSEY ENERGY COMPANY

FORM 10-Q

For the Quarterly Period Ended September 30, 2010


TABLE OF CONTENTS
PAGE
   
PART I:   FINANCIAL INFORMATION
  
   
Item 1. Financial Statements
3
   
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
24
   
Item 3. Quantitative and Qualitative Disclosures About Market Risk
37
   
Item 4. Controls and Procedures
38
   
PART II:  OTHER INFORMATION
  
   
Item 1. Legal Proceedings
39
   
Item 1A. Risk Factors
43
   
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
44
   
Item 5. Other Information
44
   
Item 6. Exhibits
49
   
SIGNATURES
50




 
  2
 
PART I: FINANCIAL INFORMATION

Item 1. Financial Statements


MASSEY ENERGY COMPANY
  
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
  
(In Thousands, Except Per Share Amounts)
  
UNAUDITED
  
                         
   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
Revenues
                        
Produced coal revenue
   $ 703,652     $ 535,531     $ 1,968,514     $ 1,819,777  
Freight and handling revenue
     65,405       52,523       201,159       171,253  
Purchased coal revenue
     28,824       14,570       70,405       43,741  
Other revenue
     12,283       38,936       68,873       72,504  
Total revenues
     810,164       641,560       2,308,951       2,107,275  
                                 
Costs and expenses
                                
Cost of produced coal revenue
     630,456       431,697       1,749,822       1,462,263  
Freight and handling costs
     65,405       52,523       201,159       171,253  
Cost of purchased coal revenue
     26,116       18,366       65,202       39,061  
Depreciation, depletion and amortization, applicable to:
                                
 Cost of produced coal revenue
     76,839       66,105       273,962       204,524  
 Selling, general and administrative
     15,725       164       31,969       2,025  
Selling, general and administrative
     23,153       21,549       75,788       63,420  
Other expense
     718       608       7,311       1,970  
Loss (Gain) on derivative instruments
     2,209       4,765       (21,795 )     (4,479 )
Total costs and expenses
     840,621       595,777       2,383,418       1,940,037  
                                 
(Loss) Income before interest and taxes
     (30,457 )     45,783       (74,467 )     167,238  
                                 
Interest income
     298       590       2,046       12,274  
Interest expense
     (25,779 )     (25,493 )     (76,225 )     (76,182 )
Gain on short-term investment
     882       -       4,662       -  
(Loss) Income before taxes
     (55,056 )     20,880       (143,984 )     103,330  
                                 
Income tax benefit (expense)
     13,632       (4,422 )     47,472       (23,254 )
                                 
Net (loss) income
   $ (41,424 )   $ 16,458     $ (96,512 )   $ 80,076  
                                 
Net (loss) income per share
                                
Basic
   $ (0.41 )   $ 0.19     $ (1.00 )   $ 0.94  
Diluted
   $ (0.41 )   $ 0.19     $ (1.00 )   $ 0.94  
                                 
Shares used to calculate Net (loss) income  per share
                                
Basic
     101,581       84,930       96,127       84,887  
Diluted
     101,581       85,662       96,127       85,371  
                                 
Dividends per share
   $ 0.06     $ 0.06     $ 0.18     $ 0.18  
 
See Notes to Condensed Consolidated Financial Statements
 
3 
 
 
MASSEY ENERGY COMPANY
  
CONDENSED CONSOLIDATED BALANCE SHEETS
  
(In Thousands, Except Per Share Amounts)
  
UNAUDITED
  
             
   
September 30,
    
December 31,
  
   
2010
    
2009
  
ASSETS
            
Current assets
            
Cash and cash equivalents
   $ 476,954     $ 665,762  
Short-term investment
     -       10,864  
Trade and other accounts receivable, less allowance of $998 and
                
$1,303, respectively
     289,527       121,577  
Inventories
     265,686       269,826  
Income taxes receivable
     14,286       10,546  
Other current assets
     173,910       235,990  
 Total current assets
     1,220,363       1,314,565  
                 
Property, plant and equipment, net
     3,181,312       2,344,770  
Intangible assets, net
     134,010       -  
Goodwill
     33,134       -  
Other noncurrent assets
     132,410       140,336  
 Total assets
   $ 4,701,229     $ 3,799,671  
                 
LIABILITIES AND SHAREHOLDERS' EQUITY
                
Current liabilities
                
Accounts payable, principally trade and bank overdrafts
   $ 227,978     $ 164,979  
Short-term debt
     3,077       23,531  
Payroll and employee benefits
     71,014       63,590  
Other current liabilities
     290,855       192,835  
Total current liabilities
     592,924       444,935  
Noncurrent liabilities
                
Long-term debt
     1,308,198       1,295,555  
Deferred income taxes
     258,605       209,230  
Pension obligation
     47,010       55,610  
Other noncurrent liabilities
     603,456       538,058  
 Total noncurrent liabilities
     2,217,269       2,098,453  
 Total liabilities
     2,810,193       2,543,388  
Shareholders’ equity
                
Capital stock
                
Preferred – authorized 20,000,000 shares without par value; none issued
     -       -  
Common – authorized 150,000,000 shares of $0.625 par value; issued
                
102,978,852 and 86,213,582 shares, respectively
     64,357       53,868  
Treasury stock, 861,439 shares at cost
     (31,822 )     -  
Additional capital
     1,334,679       568,995  
Retained earnings
     602,221       716,089  
Accumulated other comprehensive loss
     (78,399 )     (82,669 )
 Total shareholders’ equity
     1,891,036       1,256,283  
 Total liabilities and shareholders’ equity
   $ 4,701,229     $ 3,799,671  

See Notes to Condensed Consolidated Financial Statements
 
4 
 
MASSEY ENERGY COMPANY
  
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
  
(In Thousands)
  
UNAUDITED
  
   
Nine Months Ended September 30,
  
   
2010
    
2009
  
CASH FLOWS FROM OPERATING ACTIVITIES
            
Net (loss) income
   $ (96,512 )   $ 80,076  
Adjustments to reconcile Net (loss) income to Cash provided by
                
operating activities:
                
    Depreciation, depletion and amortization
     242,353       206,549  
    Impairment of Upper Big Branch assets
     63,577       -  
    Share-based compensation expense
     7,371       9,651  
    Amortization of bond discount
     15,322       14,407  
    Deferred income taxes
     (46,219 )     10,122  
    Gain on disposal of assets
     (3,284 )     (12,017 )
    Gain on reserve exchange
     (6,879 )     (24,922 )
    Reserve on note receivable
     4,953       -  
    Gain on insurance recoveries
     (5,810 )     -  
    Net gains in fair value of derivative instruments
     (5,363 )     (22,598 )
    Asset retirement obligations accretion
     13,121       10,515  
    Gain on short-term investment
     (4,662 )     -  
    Changes in operating assets and liabilities:
                
       (Increase) decrease in accounts receivable
     (118,943 )     49,319  
       Decrease in inventories
     16,082       3,339  
       Decrease (increase) in other current assets
     57,537       (57,537 )
       Increase in other assets
     (14,905 )     (1,068 )
       Increase (decrease)  in accounts payable and bank overdrafts
     38,215       (75,545 )
       (Decrease) increase in accrued income taxes
     (2,001 )     8,110  
       Increase in other accrued liabilities
     73,336       3,020  
       Increase in other noncurrent liabilities
     43,585       17,980  
       Increase in pension obligation
     2,129       16,140  
       Asset retirement obligations payments
     (4,941 )     (3,431 )
    Cash provided by operating activities
     268,062       232,110  
                 
CASH FLOWS FROM INVESTING ACTIVITIES
                
    Capital expenditures
     (278,523 )     (222,970 )
    Purchase of acquired company, net of cash acquired
     (629,977 )     -  
    Proceeds from redemption of Short-term investment
     15,526       24,262  
    Proceeds from sale of assets
     3,041       15,704  
    Proceeds from insurance recovery
     9,605       -  
       Cash utilized by investing activities
     (880,328 )     (183,004 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES
                
    Issuance of common stock
     466,707       -  
    Repurchases of common stock
     (31,822 )     -  
    Repayments of capital lease obligations
     (1,184 )     (2,175 )
    Repayments of 6.625% senior notes
     (21,949 )     -  
    Redemption of 4.75% convertible senior notes
     -       (70 )
    Proceeds from sale-leaseback transactions
     16,477       -  
    Cash dividends paid
     (17,356 )     (15,283 )
    Proceeds from stock options exercised
     11,960       1,190  
    Income tax benefit from stock option exercises
     625       227  
       Cash provided (utilized) by financing activities
     423,458       (16,111 )
(Decrease) increase in cash and cash equivalents
     (188,808 )     32,995  
Cash and cash equivalents at beginning of period
     665,762       606,997  
Cash and cash equivalents at end of period
   $ 476,954     $ 639,992  
See Notes to Condensed Consolidated Financial Statements
 
 5
 
Notes to Condensed Consolidated Financial Statements

(1)   Significant Accounting Policies

Basis of Presentation

The Condensed Consolidated Financial Statements do not include footnotes and certain financial information normally presented annually under accounting principles generally accepted in the United States (“GAAP”) and, therefore, should be read in conjunction with the Annual Report on Form 10-K of Massey Energy Company (“we,” “our,” “us” or the “Company”) for the year ended December 31, 2009.  Accounting measurements at interim dates inherently involve greater reliance on estimates than at year-end.  The results of operations for the quarterly period ended September 30, 2010 are not necessarily indicative of results that can be expected for the fiscal year ending December 31, 2010.

The Condensed Consolidated Financial Statements included herein are unaudited; however, the financial statements contain all adjustments (consisting of normal recurring accruals), which, in our opinion, are necessary to present fairly our consolidated financial position at September 30, 2010, our consolidated results of operations for the three and nine months ended September 30, 2010 and 2009, and cash flows for the nine months ended September 30, 2010 and 2009, in conformity with GAAP.

The Condensed Consolidated Financial Statements include our accounts and the accounts of our wholly-owned and majority-owned direct and indirect subsidiaries.  Significant intercompany transactions and accounts are eliminated in consolidation.  We have no independent assets or operations.  We do not have a controlling interest in any separate independent operations.  Investments in business entities in which we do not have control, but have the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method.

All of our direct and substantially all of our indirect operating subsidiaries, each such subsidiary being indirectly 100% owned by us, fully and unconditionally, jointly and severally, guarantee our obligations under the 6.875% senior notes due 2013 (“6.875% Notes”), the 3.25% convertible senior notes due 2015 (“3.25% Notes”) and the 2.25% convertible senior notes due 2024 (“2.25% Notes”).  The subsidiaries not providing a guarantee of the 6.875% Notes, the 3.25% Notes and the 2.25% Notes are minor (as defined under Securities and Exchange Commission (“SEC”) Rule 3-10(h)(6) of Regulation S-X).  See Note 7 to the Notes to Condensed Consolidated Financial Statements for a more complete discussion of debt.

We have evaluated subsequent events through the date the Condensed Consolidated Financial Statements were issued.

Goodwill

Goodwill represents the excess of the purchase price over the fair value of the net identifiable tangible and intangible assets of acquired companies.  Goodwill is not amortized; instead, it is tested for impairment annually or more frequently if indicators of impairment exist.  As a result of the acquisition of Cumberland Resources Corporation and certain affiliated companies (“Cumberland”) during the second quarter of 2010, we recorded Goodwill in our Condensed Consolidated Balance Sheet.  As purchase accounting is considered preliminary as of the date the Condensed Consolidated Financial Statements were issued, the goodwill amount recorded may be adjusted.  We have not allocated goodwill to the appropriate reporting unit(s) for the purpose of impairment testing as of the date the Condensed Consolidated Financial Statements were issued. See Note 2 to the Notes to Condensed Consolidated Financial Statements for more information.

Asset Impairment and Disposal of Long-Lived Assets

Long-lived assets, such as property, equipment, mine development costs, owned and leased mineral rights longwall panel costs and purchased intangibles subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to its
 
 6
 
estimated fair value.  The fair value is determined using the estimated undiscounted cash flows expected to be generated by the assets along with, where appropriate, market inputs.  The determination of fair value requires the use of significant judgment and estimates about assumptions that management believes are appropriate in the circumstances although it is reasonably possible that actual performance will differ from these assumptions.  If the carrying amount of an asset exceeds its estimated fair value, an impairment charge is recognized equal to the amount by which the carrying amount of the asset exceeds the estimated fair value of the asset.  See Note 5 to the Notes to Condensed Consolidated Financial Statements for more information.

Insurance Recoveries

Insurance recoveries that are deemed to be probable and reasonably estimable are recognized to the extent of the related loss.  Insurance recoveries that result in gains are recognized only when realized by settlement with the insurers.  The evaluation of insurance recoveries requires estimates and judgments about future results that affect reported amounts and certain disclosures. Actual results could differ from those estimates.

Recent Accounting Pronouncements

In January 2010, the Financial Accounting Standards Board (the “FASB”) issued an accounting standard update, amending disclosure requirements related to Fair Value Measurements and Disclosures, as follows:

1.  
Significant transfers between Level 1 and 2 shall be disclosed separately, including the reasons for the transfers; and
2.  
Information about purchases, sales, issuances and settlements shall be disclosed separately in the reconciliation of activity in Level 3 fair value measurements.

This accounting standard update is effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances and settlements in the reconciliation of activity in Level 3 fair value measurements, which are effective for interim and annual reporting periods beginning after December 15, 2010. The initial adoption of this accounting standard update did not have a material impact on our financial position or results of operations and the adoption for disclosures effective for interim and annual reporting periods beginning after December 15, 2010 is not expected to have a material impact on our cash flows, financial position or results of operations.  See Note 14 to the Notes to Condensed Consolidated Financial Statements for more information on our Fair Valu e Measurements and Disclosures.

In April 2010, the FASB issued an accounting standard update, amending disclosure requirements related to income taxes as a result of the Patient Protection and Affordable Care Act (“PPACA”).  Beginning in fiscal year 2014, the tax deduction available to us will be reduced to the extent our drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program.  Because retiree health care liabilities and the related tax impacts are already reflected in our Condensed Consolidated Financial Statements, we are required to recognize the full accounting impact of this accounting standard update in the period in which the PPACA was signed into law.  The total non-cash charge to Income tax expense related to the reduction in the tax benefit was $2.6 million, and was recorded in the firs t quarter of 2010.

(2)           Acquisition of Cumberland

On April 19, 2010, we completed the acquisition of Cumberland for a purchase price of $644.7 million in cash and 6,519,034 shares of our Common Stock.  Prior to the acquisition, Cumberland was one of the largest privately held coal producers in the United States.  The Cumberland operations include primarily underground coal mines in Southwestern Virginia and Eastern Kentucky.  We obtained an estimated 416 million tons of contiguous coal reserves, a preparation plant in Kentucky served by the CSX railroad and a preparation plant in Virginia served by the Norfolk Southern railroad.  We did not incur or assume any third-party debt as a result of the acquisition of Cumberland.  The acquisition of Cumberland increases our metallurgical coal reserves, strengthens our ability to globally mark et steam and metallurgical quality coal, and optimizes both operational best practices and working capital generation.
 
7 
 
    The acquisition of Cumberland was accounted for as a business combination.  The fair value of the total consideration transferred was $934.2 million.  The acquisition date fair value of each class of consideration transferred was as follows:


   
(In Thousands)
  
Fair value of shares of Common Stock
   $ 289,511  
Cash
     644,730  
Total purchase price
   $ 934,241  


The Fair value of shares of Common Stock transferred was determined by using the Common Stock’s closing price of $44.41 on the day of the acquisition.

The purchase price was allocated to the assets acquired and liabilities assumed based on estimated fair values determined by appraisals of the assets acquired and liabilities assumed.  Such estimates are preliminary as we have not yet received the final appraisal reports.  We expect to finalize the allocation in the fourth quarter of 2010.  The preliminary purchase price allocation was as follows:


     Purchase Price  
(In Thousands)
  
Allocation
  
         
Cash and cash equivalents
     $ 14,753  
Trade and other accounts receivable
       52,802  
Inventories
       11,942  
Other current assets
       4,140  
Net Property, Plant and Equipment
     807,779  
Intangible assets, net
     168,461  
Goodwill
     33,134  
Other Noncurrent Assets
     529  
    Total assets
 
     1,093,540  
           
Accounts payable, principally trade and bank overdrafts
     24,784  
Payroll and employee benefits
       8,648  
Other current liabilities
       24,731  
Deferred income taxes
       91,126  
Other noncurrent liabilities
       10,010  
    Total liabilities
 
     159,299  
           
    Net assets acquired
 
   $ 934,241  


As purchase accounting is considered preliminary as of the date the Condensed Consolidated Financial Statements were issued, the goodwill amount recorded may be adjusted.  We have not allocated goodwill to the appropriate reporting unit(s) for the purpose of impairment testing as of the date the Condensed Consolidated Financial Statements were issued.

Total revenue and Income before taxes reported in the Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2010 included Total revenue of $155.6 million and $294.3 million, respectively, and Income before taxes of $6.4 million and $22.3 million, respectively, related to the operations acquired in the Cumberland acquisition.
 
 8
 
The following unaudited pro forma information has been prepared for illustrative purposes only and assumes the acquisition of Cumberland occurred at the beginning of each of the periods being presented.  The unaudited pro forma results have been prepared based on estimates and assumptions that we believe are reasonable; however, they are not necessarily indicative of the consolidated results of operations had the acquisition of Cumberland occurred at the beginning of each of the periods presented or of future results of operations.


   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Thousands, Except Per Share Amounts)
  
Total revenue
                        
As reported
   $ 810,164     $ 641,560     $ 2,308,951     $ 2,107,275  
Pro forma
   $ 810,164     $ 800,681     $ 2,512,330     $ 2,539,845  
                                 
Net (loss) income
                                
As reported
   $ (41,424 )   $ 16,458     $ (96,512 )   $ 80,076  
Pro forma
   $ (41,424 )   $ 22,034     $ (85,561 )   $ 87,202  
                                 
Net (loss) income per share - Basic
                                
As reported
   $ (0.41 )   $ 0.19     $ (1.00 )   $ 0.94  
Pro forma
   $ (0.41 )   $ 0.22     $ (0.84 )   $ 0.86  
                                 
Net (loss) income per share - Dilutive
                                
As reported
   $ (0.41 )   $ 0.19     $ (1.00 )   $ 0.94  
Pro forma
   $ (0.41 )   $ 0.22     $ (0.84 )   $ 0.86  


(3)           Inventories

Inventories consisted of the following:

   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
Saleable coal
   $ 168,986     $ 179,081  
Raw coal
     38,620       36,254  
     Coal inventory
     207,606       215,335  
Supplies inventory
     58,080       54,491  
     Total inventory
   $ 265,686     $ 269,826  

Saleable coal represents coal ready for sale, including inventories designated for customer facilities under consignment arrangements of $34.0 million and $43.7 million at September 30, 2010 and December 31, 2009, respectively.  Raw coal represents coal that generally requires further processing prior to shipment to the customer.
 
9 
 

(4)           Other Current Assets

Other current assets are comprised of the following:

   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
Longwall panel costs
   $ 8,443     $ 12,041  
Deposits
     95,867       133,794  
Other
     69,600       90,155  
     Total Other current assets
   $ 173,910     $ 235,990  

During the second quarter of 2010, we impaired $5.1 million of Longwall panel costs deemed not to be recoverable at our Upper Big Branch (“UBB”) mine due to an accident that occurred in April 2010.  See Note 5 to the Notes to Condensed Consolidated Financial Statements for more information.

Deposits consists primarily of funds placed in restricted accounts with financial institutions to collateralize letters of credit that support workers’ compensation requirements, insurance and other obligations.  As of September 30, 2010 and December 31, 2009, Deposits includes $59.4 million and $46.0 million, respectively, of funds pledged as collateral to support $58.2 million and $45.1 million, respectively, of outstanding letters of credit.  In addition, Deposits at September 30, 2010 and December 31, 2009, includes $11.6 million and $12.1 million, respectively, of United States Treasury securities supporting various regulatory obligations.  As of December 31, 2009, Deposits included a $72.0 million appeal bond we had been required to post related to lit igation against us, which was released by the West Virginia Supreme Court of Appeals during the first quarter of 2010, as the final appeal of the case at the state level was resolved in our favor.  During the third quarter of 2010, we posted $9.3 million of cash as collateral for an appeal bond related to pending litigation with one of our customers (see Note 16 to the Notes to Condensed Consolidated Financial Statements for more information).

We have committed to the divestiture of certain mining equipment assets which are not part of our short-term mining plan.  At September 30, 2010 and December 31, 2009, the carrying amount of assets held for sale totaled $18.9 million and $22.3 million, respectively, and are included in Other current assets.

(5)           Property, Plant and Equipment

Property, plant and equipment is comprised of the following:


   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
Property, plant and equipment, at cost
   $ 5,515,953     $ 4,615,297  
Accumulated depreciation, depletion and amortization
     (2,334,641 )     (2,270,527 )
    Property, plant and equipment, net
   $ 3,181,312     $ 2,344,770  

During the three and nine months ended September 30, 2010, we recorded impairment charges related to the UBB tragedy of $1.4 million and $63.6 million, respectively, which are included in Depreciation, depletion and amortization applicable to Cost of produced coal revenue, in our Condensed Consolidated Statements of Income.  In accordance with relevant accounting requirements, Property, plant and equipment (which included mine development) and longwall panel costs located at or near UBB with a carrying amount of $35.4 million and $28.2 million (of which $5.1 million was considered current assets and $23.1 million noncurrent assets), respectively, were deemed to be destroyed or probable of abandonment.  Accordingly, the carrying value of the assets was completely written off.  There was approximately $14.9 million of assets at or near the UBB mine that were not impaired; our determination of recoverability related to these assets was based on our assumptions about future operations at the UBB mine and possible alternatives to accessing the related coal reserves.  Given the ongoing investigations into the cause of the UBB tragedy and the uncertainty around the future operations at the UBB mine, there is a reasonable possibility that additional impairments could be recorded in future periods.
 
10 
 
Property, plant and equipment includes gross assets under capital leases of $12.9 million at both September 30, 2010 and December 31, 2009.

 (6)           Intangible assets

As part of the acquisition of Cumberland during the second quarter of 2010, we acquired Intangible assets with a fair value of $168.5 million.  Intangible assets are comprised of the following:


(In Thousands)
  
September 30, 2010
  
       
Coal sales contracts
   $ 98,310  
Transportation contracts
     61,700  
Mining permits
     8,451  
     Intangible assets, cost
     168,461  
Accumulated amortization
     (34,451 )
     Intangible assets, net
   $ 134,010  

Our Coal sales contracts and Transportation contracts are amortized based on the actual amount of tons shipped under each contract.  Mining permits are amortized using the units-of-production method over the estimated proven and probable reserve tons.  For the three and nine months ended September 30, 2010, we recorded $17.3 million and $34.4 million, respectively, in amortization expense related to the Intangible assets.

Estimated amortization expense for Intangible assets for the next five calendar years is as follows:

    Estimated  
     Amortization  
(In Thousands)
  
Expense
  
2011
   $ 58,656  
2012
   $ 8,374  
2013
   $ 8,157  
2014
   $ 7,926  
2015
   $ 7,571  

 (7)           Debt

Debt is comprised of the following:


   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
6.875% senior notes due 2013, net of discount
            
     of $2,727 and $3,273, respectively
   $ 757,273     $ 756,727  
3.25% convertible senior notes due 2015, net of discount
                
     of $117,852 and $132,628, respectively
     541,211       526,435  
6.625% senior notes due 2010
     -       21,949  
2.25% convertible senior notes due 2024
     9,647       9,647  
Capital lease obligations
     3,144       4,328  
          Total debt
     1,311,275       1,319,086  
          Amounts due within one year
     (3,077 )     (23,531 )
          Total long-term debt
   $ 1,308,198     $ 1,295,555  

The weighted average effective interest rate of the outstanding borrowings was 7.3% at both September 30, 2010 and December 31, 2009.
 
 11
 
Convertible Debt Securities

The discount associated with the 3.25% Notes is being amortized via the effective-interest method, increasing the reported liability until the notes are carried at par value on their maturity date.  We recognized $5.0 million and $14.8 million of pre-tax non-cash interest expense for the amortization of the discount for the three and nine months ended September 30, 2010, respectively.  We recognized $4.8 million and $13.9 million of pre-tax non-cash interest expense for the amortization of the discount for the three and nine months ended September 30, 2009, respectively.

6.625% Notes

During January 2010, we redeemed at par the remaining $21.9 million of our 6.625% senior notes due 2010.

(8)           Pension Expense

Net periodic pension expense for both our qualified defined benefit pension plan and nonqualified supplemental benefit pension plan is comprised of the following components:


   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Thousands)
  
Service cost
   $ 2,536     $ 2,677     $ 7,610     $ 8,031  
Interest cost
     4,486       4,233       13,457       12,698  
Expected return on plan assets
     (4,801 )     (4,090 )     (14,404 )     (12,270 )
Recognized loss
     3,575       4,333       10,726       12,999  
Amortization of prior service cost
     1       70       4       210  
Net periodic pension expense
   $ 5,797     $ 7,223     $ 17,393     $ 21,668  

During the three and nine months ended September 30, 2010, we voluntarily contributed $5.1 million and $14.7 million, respectively, to the qualified defined benefit pension plan.  During the nine months ended September 30, 2009, we contributed $5.0 million to the qualified defined benefit pension plan; no contributions were made in the three months ended September 30, 2009.  We expect to make voluntary contributions of approximately $20 million to the qualified defined benefit pension plan in 2010.

We paid benefits to participants of the nonqualified supplemental benefit pension plan of $0.01 million and $0.02 million for the three months ended September 30, 2010 and 2009, respectively, and $0.06 million and $0.05 million for the nine months ended September 30, 2010 and 2009, respectively.

(9)           Other Noncurrent Liabilities

Other noncurrent liabilities is comprised of the following:


   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
Reclamation
   $ 226,524     $ 193,361  
Workers' compensation and black lung
     129,465       98,227  
Other postretirement benefits
     162,626       155,024  
Other
     84,841       91,446  
     Total Other noncurrent liabilities
   $ 603,456     $ 538,058  

As of September 30, 2010, Workers’ compensation and black lung includes an accrual for supplemental compensation benefits of $12.1 million related to the UBB tragedy.  See Note 16 to the Notes to Condensed Consolidated Financial Statements for more information.
 
  12
 
(10)           Black Lung and Workers’ Compensation Expense

Expenses for black lung benefits and workers’ compensation related benefits include the following components:

   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Thousands)
  
Self-insured black lung benefits:
                        
Service cost
   $ 788     $ 922     $ 2,366     $ 2,767  
Interest cost
     827       718       2,482       2,154  
Amortization of actuarial gain
     (696 )     (1,144 )     (5,697 )     (3,432 )
Subtotal black lung benefits expense
     919       496       (849 )     1,489  
Other workers' compensation and
                                
supplemental compensation
     12,817       7,536       58,302       22,601  
        Total black lung and workers'                                
compensation benefits expense
   $ 13,736     $ 8,032     $ 57,453     $ 24,090  


During the second quarter of 2010, we recorded a one time charge of $25.4 million for workers’ compensation and supplemental compensation benefits related to the UBB tragedy.  The workers’ compensation benefits are being measured and paid from our existing plan.  Both the workers’ compensation and supplemental compensation benefits were calculated, in consultation with independent actuaries, who after review and approval by management with regards to actuarial assumptions, including discount rate, prepared an evaluation of the self-insured liabilities.  Actual experience in settling these liabilities could differ from these estimates.

Payments for benefits, premiums and other costs related to black lung, workers’ compensation and supplemental compensation benefit liabilities were $15.4 million and $37.0 million for the three and nine months ended September 30, 2010, respectively, and $6.2 million and $23.8 million for the three and nine months ended September 30, 2009, respectively.

Certain of our operations are fully insured by a third-party insurance provider for black lung claims.

The PPACA amended previous legislation related to coal workers’ pneumoconiosis (black lung), providing automatic extensions of awarded lifetime benefits to surviving spouses and providing changes to the legal criteria used to assess and award claims.  The impact of these changes to our current population of beneficiaries and claimants results in an estimated $3.6 million increase to our obligation.  During the second quarter of  2010, we recorded this estimate as an increase to our black lung liability and a decrease to our actuarial gain included in “Accumulated other comprehensive loss” on our Condensed Consolidated Balance Sheets.  This increase to our obligation excludes the impact of the reevaluation of closed claims as we do not have sufficient information to determi ne what, if any, such claims will be filed. We will continue to evaluate the impact of these changes on such claims and record any necessary charges in the period in which the additional liability is estimable.  We do not believe the impact of these changes will significantly impact our financial position or results of operations.

 
13 
 

(11)           Other Postretirement Benefits

Other postretirement benefits cost includes the following components:


   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Thousands)
  
Service cost
   $ 558     $ 978     $ 1,675     $ 2,935  
Interest cost
     2,381       2,504       7,143       7,513  
Recognized loss
     794       576       2,383       1,728  
Amortization of prior service credit
     (720 )     (188 )     (2,159 )     (564 )
Other postretirement benefits cost
   $ 3,013     $ 3,870     $ 9,042     $ 11,612  

Payments for benefits related to Other postretirement benefits were $1.6 million and $4.6 million for the three and nine months ended September 30, 2010, respectively, and $2.3 million and $5.6 million for the three and nine months ended September 30, 2009, respectively.

The PPACA may potentially impact our costs to provide healthcare benefits to our eligible active and certain retired employees.  The PPACA has both short-term and long-term implications on healthcare benefit plan standards.  Implementation of this legislation is planned to occur in phases, with plan standard changes taking effect beginning in 2010, but to a greater extent with the 2011 benefit plan year and extending through 2018.  Plan standard changes that could affect us in the short term include raising the maximum age for covered dependents to receive benefits, the elimination of lifetime dollar limits per covered individual and restrictions on annual dollar limits per covered individual, among other standard requirements.  Plan standard changes that could affect us in the long term include a tax on “high cost” plans (excise tax) and the elimination of annual dollar limits per covered individual, among other standard requirements.  We are currently analyzing this legislation to determine the full extent of the impact of the required plan standard changes on our employee healthcare plans and the resulting costs. Beginning in 2018, the PPACA will impose a 40% excise tax on employers to the extent that the value of their healthcare plan coverage exceeds certain dollar thresholds.  We anticipate that certain government agencies will provide additional regulations or interpretations concerning the application of this excise tax.  Until these regulations or interpretations are published, it is impractical to reasonably estimate the impact of the excise tax on our future healthcare costs or postretirement benefit obligation.  Accordingly, as of September 30, 2010, we have not made any changes to our assumptions used to determine our postretirement b enefit obligation.  With the exception of the excise tax, we do not believe any other plan standard changes will be significant to our future healthcare costs for eligible active employees and our postretirement benefit obligation for certain retired employees. However, we will need to continue to evaluate the impact of the PPACA in future periods as additional information and guidance becomes available.

(12)           Earnings Per Share

The number of shares of Common Stock used to calculate basic earnings per share for the three and nine months ended September 30, 2010 and 2009, is based on the weighted average of outstanding shares of Common Stock during the respective periods.  The number of shares of Common Stock used to calculate diluted earnings per share is based on the number of shares of Common Stock used to calculate basic earnings per share plus the dilutive effect of stock options and other stock-based instruments held by our employees and directors during each period and debt securities currently convertible into shares of Common Stock during each period.  The effect of dilutive securities issuances in the amount of 0.5 million and 0.7 million shares of Common Stock for the three and nine months ended September 30, 2010, respectively, and 1.2 million and 2.8 million shares of Common Stock for the three and nine months ended September 30, 2009, respectively, were excluded from the calculation of diluted (loss) income per share of Common Stock, as such inclusion would result in antidilution.
 
14 
 
The computations for basic and diluted (loss) income per share are based on the following per share information:

   
Three Months Ended
      
Nine Months Ended
  
   
September 30,
      
September 30,
  
   
2010
    
2009
      
2010
    
2009
  
      (In Thousands, Except Per Share Amounts)  
Numerator:
                          
Net (loss) income - numerator for basic
   $ (41,424 )   $ 16,458       $ (96,512 )   $ 80,076  
Effect of convertible notes
     -       44         -       130  
Adjusted net (loss) income - numerator
                                  
  for diluted
   $ (41,424 )   $ 16,502       $ (96,512 )   $ 80,206  
                                   
Denominator:
                                  
Weighted average shares - denominator
                                  
 for basic
     101,581       84,930         96,127       84,887  
Effect of stock options/restricted stock
     -       444         -       195  
Effect of convertible notes
     -       288         -       289  
Adjusted weighted average
                                  
  shares - denominator for diluted
     101,581       85,662         96,127       85,371  
                                   
Net (loss) income per share:
                                  
Basic
   $ (0.41 )   $ 0.19       $ (1.00 )   $ 0.94  
Diluted
   $ (0.41 )   $ 0.19       $ (1.00 )   $ 0.94  


The 2.25% Notes are convertible by holders into shares of Common Stock during certain periods under certain circumstances.  The 2.25% Notes were not eligible for conversion at September 30, 2010.  If all of the 2.25% Notes outstanding at September 30, 2010 had been eligible for conversion and were converted at that date, we would have issued 287,113 shares of Common Stock.

The 3.25% Notes are convertible under certain circumstances and during certain periods into (i) cash, up to the aggregate principal amount of the 3.25% Notes subject to conversion and (ii) cash, Common Stock or a combination thereof, at our election in respect to the remainder (if any) of our conversion obligation.  As of September 30, 2010, the 3.25% Notes had not reached the specified threshold for conversion.

(13)           Derivative Instruments

Upon entering into each coal sales and coal purchase contract, we evaluate each of our contracts to determine if they qualify for the normal purchase normal sale (“NPNS”) exception prescribed by current accounting guidance.  We use coal purchase contracts to supplement our produced and processed coal in order to provide coal to meet customer requirements under sales contracts.  We are exposed to certain risks related to coal price volatility.  The purchases and sales contracts we enter into allow us to mitigate a portion of the underlying risk associated with coal price volatility.  The majority of our contracts qualify for the NPNS exception and therefore are not accounted for at fair value.  For those contracts that do not qualify for the NPNS exception at inception or lo se their designation at some point during the duration of the contract, the contracts are required to be accounted for as derivative instruments and must be recognized as assets or liabilities and measured at fair value.  Those contracts that do not qualify for the NPNS exception have not been designated as cash flow or fair value hedges and, accordingly, the net change in fair value is recorded in current period earnings.  Our coal sales and coal purchase contracts that do not qualify for the NPNS exception as prescribed by current accounting guidance are offset on a counterparty-by-counterparty basis for derivative instruments executed with the same counterparty under a master netting arrangement.

 
15 
 
Tons outstanding under coal purchase and coal sales contracts that do not qualify for the NPNS exception are as follows:


   
September 30,
    
December 31,
  
   
2010
    
2009
  
   
(In Thousands)
  
Purchase contracts
     750       980  
Sales contracts 
     1,634       1,120  
 
The fair values of our purchase and sales derivative contracts have been aggregated in the Condensed Consolidated Balance Sheets as of September 30, 2010 and December 31, 2009, as follows:


   
September 30,
    
December 31,
  
   
2010
    
2009
  
   
(In Thousands)
  
Other current assets
   $ 20,801     $ 30,564  
Other noncurrent assets
     4,073       -  
Total aggregated derivative balance
   $ 24,874     $ 30,564  


We have recorded net gains related to coal sales and purchase contracts that did not qualify for the NPNS exception in the Condensed Consolidated Statements of Income under the caption Loss (Gain) on derivative instruments.


   
Three Months Ended
    
Nine Months Ended
  
   
September 30,
    
September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Thousands)
    
(In Thousands)
  
Realized (gains) losses due to settlements
                        
   on existing contracts
   $ (8,775 )   $ 2,327     $ (27,485 )   $ 18,119  
Unrealized losses (gains) on
                                
   outstanding contracts
     10,984       2,438       5,690       (22,598 )
   Loss (Gain) on derivative instruments   $    2,209     $ 4,765     $ (21,795 )   $ (4,479 )


(14)           Fair Value

Financial and non-financial assets and liabilities that are required to be measured at fair value must be categorized based upon the levels of judgment associated with the inputs used to measure their fair value.  Hierarchical levels – directly related to the amount of subjectivity associated with the inputs used to determine the fair value of financial assets and liabilities – are as follows:

 
●
Level 1 – Inputs are unadjusted, quoted prices in active markets for identical assets or liabilities at the measurement date.
 
 
●
Level 2 – Inputs (other than quoted prices included in Level 1) are either directly or indirectly observable for the assets or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
 
 
●
Level 3 – Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date.  Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model.


 
16 
 

Each major category of financial assets and liabilities measured at fair value on a recurring basis are categorized in the tables below based upon the lowest level of significant input to the valuations.


   
September 30, 2010
  
   
(In Thousands)
  
   
Level 1
    
Level 2
    
Level 3
    
Total
  
Fixed income securities
                        
U.S. Treasury securities
   $ 11,635     $ -     $ -     $ 11,635  
Certificates of Deposit
     50,031       -       -       50,031  
Money market funds
                                
U.S. Treasury money market fund
     45,398       -       -       45,398  
Other money market funds
     398,362       -       -       398,362  
Derivative instruments
     -       24,874       -       24,874  
Total securities
   $ 505,426     $ 24,874     $ -     $ 530,300  
                                 
                                 
   
December 31, 2009
  
   
(In Thousands)
  
   
Level 1
    
Level 2
    
Level 3
    
Total
  
Fixed income securities
                                
U.S. Treasury securities
   $ 12,147     $ -     $ -     $ 12,147  
Money market funds
                                
U.S. Treasury money market fund
     74,103       -       -       74,103  
Other money market funds
     689,470       -       -       689,470  
Derivative instruments
     -       30,564       -       30,564  
Short-term investment
     -       -       10,864       10,864  
Total securities
   $ 775,720     $ 30,564     $ 10,864     $ 817,148  

Fixed income securities and money market funds

All fixed income securities are deposits, consisting of obligations of the United States Treasury and Certificates of Deposit (all insured by the Federal Deposit Insurance Corporation), supporting various regulatory obligations.  All investments in money market funds are cash equivalents or deposits pledged as collateral and are invested in prime money market funds and Treasury-backed funds.  Included in the money market funds are $59.4 million of funds pledged as collateral to support $58.2 million of outstanding letters of credit.  See Note 4 to the Notes to Condensed Consolidated Financial Statements for more information on deposits.

Derivative Instruments

Certain of our coal sales and coal purchase contracts that do not qualify for the NPNS exception at inception or lose their designation at some point during the life of the contract are accounted for as derivative instruments and are required to be recognized as assets or liabilities and measured at fair value.  To establish fair values for these contracts, we use bid/ask price quotations obtained from independent third-party brokers. We also consider the risk of nonperformance of or nonpayment by the counterparties when determining the fair values for these contracts by evaluating the credit quality and financial condition of each counterparty.  We could experience difficulty in valuing our derivative instruments if the number of third-party brokers should decrease or market liquidity is reduced.  See No te 13 to the Notes to Condensed Consolidated Financial Statements for more information.

Asset and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances, for example, when there is evidence of impairment.  In accordance with relevant accounting requirements, Property, plant and equipment (which included mine development) and longwall panel costs located at or near the UBB mine
 
17 
 
with a carrying amount of $35.4 million and $28.2 million (of which $5.1 million was considered current assets and $23.1 million noncurrent assets), respectively, was deemed to be destroyed or probable of abandonment.  Accordingly, the carrying value of the assets was completely written off.  For impairment tests, we compare the carrying value of the asset tested to its estimated fair value. The fair value is determined using the estimated undiscounted cash flows expected to be generated by the assets along with, where appropriate, market inputs.  Given the assets were deemed to be destroyed or probable of abandonment, the fair value was estimated to be $0.  The determination of fair value was based on our assumptions about future operations at the UBB mine and possible alternatives to accessing the related coal reserves.  Given the ongoing investigations into the cause of the UBB tr agedy and the uncertainty around the future operations at the UBB mine, there is a reasonable possibility that additional impairments could be recorded in future periods.

Short-Term Investment

Short-term investment at December 31, 2009 was comprised of an investment in the Reserve Primary Fund (“Primary Fund”), a money market fund that suspended redemptions and is being liquidated.  We determined that our investment in the Primary Fund as of December 31, 2009, no longer met the definition of a security, within the scope of current accounting guidance, since the equity investment no longer had a readily determinable fair value.  Therefore, the investment was classified as a short-term investment, subject to the cost method of accounting, on our Condensed Consolidated Balance Sheet.

Assets Measured at Fair Value on a Recurring Basis Using Significant Unobservable Inputs (Level 3):


   
Short-term
  
(In Thousands)
  
investment
  
       
Balance at December 31, 2009
   $ 10,864  
Transfers out of Level 3
     (15,526 )
Total gains or (losses) realized/unrealized included in earnings
     4,662  
Purchases, issuances, sales and settlements
     -  
Balance at September 30, 2010
   $ -  
         
Total gains or (losses) for the period included in earnings attributable to the change
        
in unrealized gains or losses relating to assets still held at the reporting date
   $ -  

At December 31, 2009, our investment in the Primary Fund was $10.9 million, net of a $6.5 million write-down recorded in 2008, which represents the difference between cost and estimated fair value.  During 2010, we received distributions totaling $15.6 million, including $0.9 million in July 2010. We recorded a $4.7 million gain on short-term investments which represents the difference between book value and total redemptions received.  As of September 30, 2010, the estimated fair value of our unrecovered investment of $1.8 million in the Primary Fund was $0.

Other Financial Instruments

The following methods and assumptions were used to estimate the fair value of those financial instruments that are not required to be carried at fair value within our Condensed Consolidated Balance Sheets:

Short-term debt: The carrying amount reported in the Condensed Consolidated Balance Sheets for short-term debt approximates its fair value due to the short-term maturity of these instruments.

Long-term debt: The fair values of long-term debt are estimated using the most recent market prices quoted on or before September 30, 2010.

 
18 
 

The carrying amounts and fair values of these financial instruments are presented in the table below.  The carrying value of the 3.25% Notes reflected in Long-term debt in the table below reflects the full face amount of $659 million, which is reflected net of discount in the Condensed Consolidated Balance Sheets.


   
September 30, 2010
       December 31, 2009  
   
Carrying Value
    
Fair Value
    
Carrying Value
      
Fair Value
  
   
(In Thousands)
  
Short-term debt
   $ 3,077     $ 3,077     $ 23,531       $ 23,465  
Long-term debt
   $ 1,428,710     $ 1,368,430     $ 1,428,710       $ 1,348,699  


 (15)           Common Stock

Common Stock Issuance

On March 23, 2010, we completed a registered underwritten public offering of 9,775,000 shares of our Common Stock at a public offering price of $49.75 per share, resulting in proceeds to us of $466.8 million, net of fees.  In April 2010, we used the net proceeds of this offering and 6,519,034 shares of Common Stock (fair valued at $289.5 million on the day of the acquisition) to fund a portion of the consideration for the acquisition of Cumberland.  See Note 2 to the Notes to Condensed Consolidated Financial Statements for a more complete discussion of the acquisition of Cumberland.

Common Stock Repurchases

During the second quarter of 2010, we repurchased 861,439 shares of Common Stock at an average price of $36.92, for a total cost of $31.8 million.  The Common Stock was repurchased under a stock repurchase program (the “Repurchase Program”) authorized by our Board of Directors on November 14, 2005, authorizing us to repurchase shares of Common Stock from time to time up to an aggregate amount not to exceed $500 million, as market conditions warrant and existing covenants permit.  Prior to this share repurchase, we had $420 million available under the 2005 authorization.  We did not repurchase any shares in the third quarter of 2010.  Shares repurchased in 2010 have been recorded as Treasury stock in the Condensed Consolidated Balance Sheet.

(16)           Contingencies

West Virginia Flooding

Since August 2004, five of our subsidiaries have been sued in six civil actions filed in the Circuit Courts of Boone, McDowell, Mingo, Raleigh, Summers and Wyoming Counties, West Virginia, for alleged property damages and personal injuries arising out of flooding on or about May 2, 2002.  These complaints covered approximately 350 plaintiffs seeking unquantified compensatory and punitive damages from approximately 35 defendants.  Of these cases two were dismissed by the court without prejudice for failure to prosecute, two were dismissed by plaintiffs voluntarily and with prejudice, and one was settled for a nominal amount.  Only the Mingo County case remains active.

Since May 2006, we and 12 of our subsidiaries have been sued in three civil actions filed in the Circuit Courts of Logan and Mingo Counties, West Virginia, for alleged property damages and personal injuries arising out of flooding between May 30 and June 4, 2004.  These complaints cover approximately 425 plaintiffs seeking unquantified compensatory and punitive damages from approximately 52 defendants.  Four of our subsidiaries have been dismissed without prejudice from one of the Logan County cases.

We believe the remaining cases will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.
 
19 
 

West Virginia Trucking

Since January 2003, an advocacy group and residents in Boone, Kanawha, Mingo and Raleigh Counties, West Virginia, filed 17 suits in the Circuit Courts of Kanawha and Mingo Counties, West Virginia, against 12 of our subsidiaries.  Plaintiffs alleged that defendants illegally transported coal in overloaded trucks, causing damage to state roads, thereby interfering with plaintiffs’ use and enjoyment of their properties and their right to use the public roads. Plaintiffs seek injunctive relief and compensatory and punitive damages.  The Supreme Court of Appeals of West Virginia (“WV Supreme Court”) referred the consolidated lawsuits, and similar lawsuits against other coal and transportation companies not involving our subsidiaries, to the Circuit Court of Lincoln County, West Virginia (“Circuit Court”), to be handled by a mass litigation panel judge. Plaintiffs filed motions requesting class certification. On June 7, 2007, plaintiffs voluntarily dismissed their public nuisance claims seeking monetary damages for road and bridge repairs.  Plaintiffs also agreed to an order limiting any damages for nuisance to two years prior to the filing of any suit.  A motion to dismiss any remaining public nuisance claims was resisted by plaintiffs and argued at hearings on December 14, 2007 and June 25, 2008.  No rulings on these matters have been made.  Defendants filed a motion requesting that the mass litigation panel judge recommend to the WV Supreme Court that the cases be sent back to the circuit courts of origin for resolution.  That motion was verbally denied as to those cases in which our subsidiaries are defendants, and a class certification hearing was held on October 21, 2009.  To date, no decision has been rendered by the Circuit Cou rt on the class certification issues.  No date has been set for trial.  We believe we have insurance coverage applicable to these items and that they will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.

Well Water Suits

Since September 2004, approximately 738 plaintiffs have filed approximately 400 suits against us and our subsidiary, Rawl Sales & Processing Co., in the Circuit Court of Mingo County, West Virginia (“Mingo Court”), for alleged property damage and personal injuries arising out of slurry injection and impoundment practices allegedly contaminating plaintiffs’ water wells. Plaintiffs seek injunctive relief and compensatory damages in excess of $170 million and unquantified punitive damages.  Specifically, plaintiffs are claiming that defendants’ activities during the period of 1978 through 1987 rendered their property valueless and request monetary damages to pay, inter alia, the value of their property and future water bills.  In addition, many plaintiffs are also claiming that their exposu re to the contaminated well water caused neurological injury or physical injury, including cancers, kidney problems and gall stones.  Finally, all plaintiffs claimed entitlement to medical monitoring for the next 30 years and have requested unliquidated compensatory damages for pain and suffering, annoyance and inconvenience and legal fees.  On April 30, 2009, the Mingo Court held a mandatory settlement conference. At that settlement conference, all plaintiffs agreed to settle and dismiss their medical monitoring claims.  Additionally, 180 plaintiffs agreed to settle all of their remaining claims and be dismissed from the case.  All settlements to date will be funded by insurance proceeds.  Plaintiffs are challenging the medical monitoring settlement.  A motion to enforce the medical monitoring settlement has been filed.  No ruling has been made.  There are currently 585 plaintiffs remaining.  Mediation of all pending s uits is scheduled to begin in November, 2010 in Charleston, West Virginia.  A trial date has been set for August 2011, if the mediation fails to lead to a settlement.

Beginning in December 2008, we and certain of our subsidiaries along with several other companies were sued in numerous actions in Boone County, West Virginia involving approximately 370 plaintiffs alleging well water contamination resulting from coal mining operations.  The claims mirror those made above in the separate action before the Mingo Court.  The separate civil actions have been consolidated for discovery purposes with trial for 267 plaintiffs scheduled for October 25, 2011.  No trial date is set for the remaining approximately 102 plaintiffs.

We do not believe there was any contamination caused by our activities or that plaintiffs suffered any damage and, therefore, we do not believe we have a probable loss related to these matters.  We plan to vigorously contest these claims.  We believe that we have insurance coverage applicable to these matters and have initiated litigation against our insurers to establish that coverage.  At this time, we believe that the litigation by the plaintiffs will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.

 
20 
 

Surface Mining Fills

Since September 2005, three environmental groups sued the United States Army Corps of Engineers (“Corps”) in the United States District Court for the Southern District of West Virginia (the “District Court”), asserting the Corps unlawfully issued permits to four of our surface mines to construct mining fills. The suit alleges the Corps failed to comply with the requirements of both Section 404 of the Clean Water Act and the National Environmental Policy Act, including preparing environmental impact statements for individual permits. We intervened in the suit to protect our interests. On March 23, 2007, the District Court rescinded four of our subsidiaries’ permits, resulting in the temporary suspension of mining at these surface mines. We appealed that ruling to the United States Court of Appeals for the Fourth Circuit (the “Fourth Circuit Court”). On April 17, 2007, the District Court partially stayed its ruling, permitting mining to resume in certain fills that were already under construction. On June 14, 2007, the District Court issued an additional ruling, finding the Corps improperly approved placement of sediment ponds in streams below fills on the four permits in question.  The District Court subsequently modified its ruling to allow these ponds to remain in place, as the ponds and fills have already been constructed.  The District Court’s ruling could impact the issuance of permits for the placement of sediment ponds for future operations. If the permits for the fills or sediment ponds are ultimately held to be unlawfully issued, production could be affected at these surface mines, and the process of obtaining new Corps permits for all surface mines could become more difficult. We appealed both rulings to the Fourth Circuit Court.  On February 13, 2009, the Fourth Circuit Court reversed the prior rulings of the District Court and remanded the matter for further proceedings. On March 30, 2009, the plaintiffs requested that the Fourth Circuit Court reconsider the case.  The request was denied on May 20, 2009. On August 26, 2009, the plaintiffs filed their request with the United States Supreme Court to review the Fourth Circuit Court’s decision.  Our subsidiaries’ response was due on August 5, 2010. However, on August 3, 2010, the plaintiffs moved to withdraw their petition in the wake of a new policy adopted by the Corps and the Environmental Protection Agency on July 30, 2010 for assessing “stream ecosystem structure and function” for Appalachian surface coal mining. The motion to withdraw the petition for certiorari was granted, thereby finalizing the Fourth Circuit Court’s decision.

Customer Disputes

We have customers who claim they did not receive, or did not timely receive, all of the coal required to be shipped to them during 2008 (“unshipped tons”). In such cases, it is typical for a customer and coal producer to agree upon a schedule for shipping unshipped tons in subsequent years.  A few of our customers, however, filed claims for cover damages, which damages are equal to the difference between the contract price of the coal that was not delivered and the market price of replacement coal or comparable quality coal. We resolved a number of these claims in 2009 and 2010, while discussions with other customers remain ongoing.

We believe we have strong defenses to the remaining claims for cover damages.  In many cases, there was untimely or insufficient delivery of railcars by the rail carrier or the customer.  In other cases, factors beyond our control caused production or shipment problems.  Additionally, we believe that certain customers previously agreed to accept unshipped tons in subsequent years.  We believe that all of these factors, and other factors, provide defenses to claims or potential claims for unshipped tons.

Separately, we are currently in litigation with one customer regarding whether or not binding contracts for the sale of coal were reached.  We maintain that this customer improperly terminated a signed, higher-priced contract; the customer argues that it was only required to purchase coal under a purported agreement reached by email. On February 12, 2010, we received a decision from an arbitration panel awarding this customer $10.5 million on the grounds that the purported agreement by email was valid and that the higher-priced contract was invalid.  We believed that the arbitration panel’s decision as to the validity of the higher-priced contract was beyond the panel’s jurisdiction of the award, which amounts to $8.2 million, and challenged that decision in federal court.  On June 2, 2010, th e federal court rejected our challenge.  We are appealing this matter to the United States Court of Appeals for the Fourth Circuit Court.  While we will vigorously pursue this appeal, we have accrued the remainder of the judgment in Other current liabilities at September 30, 2010.  We have paid $2.3 million for the award relating to the panels’ decision that the agreement by email was valid, but have not yet paid the portion of the award under appeal.

We believe that we have strong defenses to the other claims and potential claims and further feel that many or all of these claims may be resolved without trial. We have recorded an accrual for our best estimate of probable
 
21 
 
losses related to these matters. While we believe that all of these matters discussed above will be resolved without a material adverse impact on our cash flows, results of operations or financial condition, it is reasonably possible that our judgments regarding some or all of these matters could change in the near term. We believe the aggregate exposure related to these claims in excess of our accrual is up to $4 million of charges that would affect our future operating results and financial position.

Spartan Unfair Labor Practice Matter & Related Age Discrimination Class Action

In 2005, the United Mine Workers of America (“UMWA”) filed an unfair labor practice charge with the National Labor Relations Board (“NLRB”) alleging that one of our subsidiaries, Spartan Mining Company (“Spartan”), discriminated on the basis of anti-union animus in its employment offers.  The NLRB issued a complaint and an NLRB Administrative Law Judge (“ALJ”) issued a recommended decision making detailed findings that Spartan committed a number of unfair labor practice violations and awarding, among other relief, back pay damages to union discriminatees.  On September 30, 2009, the NLRB upheld the ALJ’s recommended decision.  Spartan has appealed the NLRB’s decision to the Fourth Circuit Court. We have no insurance coverage applicable to this un fair labor practice matter; however, its resolution is not expected to have a material impact on our cash flows, results of operations or financial condition.

Upper Big Branch Mine

On April 5, 2010, an accident occurred at the Upper Big Branch mine of our Performance resource group, tragically resulting in the deaths of 29 miners and seriously injuring two others.  The Federal Mine Safety and Health Administration (“MSHA”) and the State of West Virginia have undertaken a joint investigation into the cause of the UBB tragedy.  We also have commenced our own investigation.  We believe these investigations will continue for the foreseeable future, and we cannot provide any assurance as to their outcome, including whether we become subject to possible civil penalties or enforcement actions.  In order to accommodate these investigations, the UBB mine will be closed for an extended period of time, the length of which we cannot predict at this time.  It is a lso possible that we may decide or be required by regulators to permanently close the UBB mine.  We self-insure our underground mining equipment, including longwalls, at or near the UBB mine.  We do not currently carry business interruption insurance for the UBB mine.  We have third-party general liability insurance coverage that applies to litigation risk, which coverage we believe applies to litigation stemming from the UBB tragedy.

While updated analyses will continue in future quarters, we have recorded our best estimate of probable losses related to this matter.  The most significant components of these losses related to: the benefits being provided to the families of the fallen miners (see Note 10 to the Notes to Condensed Consolidated Financial Statements for more information about the significant benefits provided), costs associated with the rescue and recovery efforts, possible legal and other contingencies, and asset impairment charges (see Note 5 to the Notes to Condensed Consolidated Financial Statements for more information).  We have recorded a $78 million liability in Other current liabilities at September 30, 2010, which represents our best estimate of the probable loss related to potential future litigation settlements associate d with the UBB tragedy.  Two of the families have filed wrongful death suits against us, while seven families have signed agreements to settle their claims (three of which have been finalized after receiving the required judicial approval).  Insurance recoveries related to our general liability insurance policy that are deemed probable and that are reasonably estimable have been recognized in the Condensed Consolidated Statements of Income to the extent of the related losses, less applicable deductibles.  Such recognized recoveries for litigation settlements associated with the UBB tragedy totaled $78 million and are included in Trade and other accounts receivable at September 30, 2010.

Given the uncertainty of the outcome of current investigations, including whether we become subject to possible civil penalties or enforcement actions, it is possible that the total costs incurred related to this tragedy could exceed our current estimates.  As of September 30, 2010, we believe that the reasonably possible aggregate loss related to these claims in excess of amounts currently recorded cannot be estimated.  It is possible, however, that the ultimate liabilities in the future with respect to these claims, in the aggregate, may be material.  We will continue to review the amount of any necessary accruals, potential asset impairments, or other related expenses and record the charges in the period in which the determination is made and an adjustment is required.
 
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Clean Water Act Citizens’ Suits

 The Sierra Club and others have filed two citizens’ suits against several of our subsidiaries in federal court in the Southern District of West Virginia alleging violations of the terms of our water discharge permits. One of the cases is limited to allegations that two of our subsidiaries, Independence Coal Company and Jacks Branch Coal Company, are violating limits on the allowable concentrations of selenium in their discharges of storm water from several surface mines. The other action is limited to claims that several of our subsidiaries are violating discharge limits on substances other than selenium, such as aluminum. The plaintiffs in these cases seek both a civil penalty and injunctive relief.

In the non-selenium case, we have argued that the alleged violations are contemplated by an existing consent decree with the United States government and should not be the subject of a new lawsuit.  In the selenium case, we have argued that the limits on selenium concentrations in our discharges have been stayed by an order of the West Virginia Environmental Quality Board and therefore cannot be the subject of a Clean Water Act case until after those limits become effective. The plaintiffs have nonetheless filed a motion for summary judgment in the selenium case, arguing that we are in violation of our permit limits despite the stays.

Other Legal Proceedings

We are parties to a number of other legal proceedings, incident to our normal business activities.  These include, for example, contract disputes, personal injury claims, property damage claims, environmental issues, and employment and safety matters. While we cannot predict the outcome of any of these proceedings, based on our current estimates we do not believe that any liability arising from these matters individually or in the aggregate should have a material adverse impact upon our consolidated cash flows, results of operations or financial condition.  It is possible, however, that the ultimate liabilities in the future with respect to these lawsuits and claims, in the aggregate, may be materially adverse to our cash flows, results of operations or f inancial condition.





* * * * * * * *

 
23 
 
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis is provided to increase understanding of, and should be read in conjunction with, the Condensed Consolidated Financial Statements and accompanying notes included in this Quarterly Report on Form 10-Q and our Annual Report on Form 10-K for the year ended December 31, 2009.

Forward-Looking Information

From time to time, we make certain comments and disclosures in reports, including this report, or through statements made by our officers that may be forward-looking in nature.  Examples include statements related to our future outlook, anticipated capital expenditures, projected cash flows and borrowings and sources of funding.  We caution readers that forward-looking statements, including disclosures that use words such as “target,” “goal,” “objective,” “believe,” “anticipate,” “expect,” “estimate,” “intend,” “may,” “plan,” “project,” “will” and similar words or statements are subject to certain risks, trends and uncertainties that could cause actual cash flows, results o f operations, financial condition, cost reductions, acquisitions, dispositions, financing transactions, operations, expansion, consolidation and other events to differ materially from the expectations expressed or implied in such forward-looking statements.  Any forward-looking statements are also subject to a number of assumptions regarding, among other things, future economic, competitive and market conditions.  These assumptions are based on facts and conditions, as they exist at the time such statements are made as well as predictions as to future facts and conditions, the accurate prediction of which may be difficult and involve the assessment of circumstances and events beyond our control.  We disclaim any intent or obligation to update these forward-looking statements unless required by securities law, and we caution the reader not to rely on them unduly.

We have based any forward-looking statements we have made on our current expectations and assumptions about future events and circumstances that are subject to risks, uncertainties and contingencies that could cause results to differ materially from those discussed in the forward-looking statements, including, but not limited to:

 
(i)
our cash flows, results of operations or financial condition;
 
 
(ii)
the impact of the UBB mine tragedy;
 
 
(iii)
the successful completion of acquisition, disposition or financing transactions and the effect thereof on our business;
 
 
(iv)
our ability to successfully integrate the operations we acquire, including as a result of the Cumberland acquisition;
 
 
(v)
governmental policies, laws, regulatory actions and court decisions affecting the coal industry or our customers’ coal usage;
 
 
(vi)
legal and administrative proceedings, settlements, investigations and claims and the availability of insurance coverage related thereto;
 
 
(vii)
inherent risks of coal mining beyond our control, including weather and geologic conditions or catastrophic weather-related damage;
 
 
(viii)
inherent complexities make it more difficult and costly to mine in Central Appalachia than in other parts of the United States;
 
 
(ix)
our production capabilities to meet market expectations and customer requirements;
 
 
(x)
our ability to obtain coal from brokerage sources or contract miners in accordance with their contracts;
 
 
(xi)
our ability to obtain and renew permits necessary for our existing and planned operations in a timely manner;
 
 
(xii)
the cost and availability of transportation for our produced coal;
 
 
(xiii)
our ability to expand our mining capacity;
 
 
(xiv)
our ability to manage production costs, including labor costs;
 
 
(xv)
adjustments made in price, volume or terms to existing coal supply agreements;
 
24 
 
 
(xvi)
the worldwide market demand for coal, electricity and steel;

 
(xvii)
environmental concerns related to coal mining and combustion and the cost and perceived benefits of alternative sources of energy such as natural gas and nuclear energy;
 
 
(xviii)
competition among coal and other energy producers, in the United States and internationally;
 
 
(xix)
our ability to timely obtain necessary supplies and equipment;
 
 
(xx)
our reliance upon and relationships with our customers and suppliers;
 
 
(xxi)
the creditworthiness of our customers and suppliers;
 
 
(xxii)
our ability to attract, train and retain a skilled workforce to meet replacement or expansion needs;
 
 
(xxiii)
our assumptions and projections concerning economically recoverable coal reserve estimates;
 
 
(xxiv)
our failure to enter into anticipated new contracts;
 
 
(xxv)
future economic or capital market conditions;
 
 
(xxvi)
foreign currency fluctuations;
 
 
(xxvii)
the availability and costs of credit, surety bonds and letters of credit that we require;
 
 
(xxviii)
the lack of insurance against all potential operating risks;
 
 
(xxix)
our assumptions and projections regarding pension and other post-retirement benefit liabilities;
 
 
(xxx)
our interpretation and application of accounting literature related to mining specific issues; and
 
 
(xxxi)
the successful implementation of our strategic plans and objectives for future operations and expansion or consolidation.

We are including this cautionary statement in this Quarterly Report on Form 10-Q to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf, of us.  Any forward-looking statements should be considered in context with the various disclosures made by us about our businesses in our public filings with the SEC, including without limitation the risk factors more specifically described in Part II Item 1A. Risk Factors of our Quarterly Reports on Form 10-Q, including this Quarterly Report on Form 10-Q, and in Part I Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2009.

Available Information

We file our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxy statements and other information with the SEC.  Our SEC filings are available to the public over the Internet at the SEC’s website at www.sec.gov.  You may also read and copy any document we file at the SEC’s public reference room at 100 F Street, N.E., Washington, D.C. 20549.  Please call the SEC at 1-800-SEC-0330 for further information on the public reference room.  We make available, free of charge through our Internet website, www.masseyenergyco.com (which website is not incorporated by reference into this report), our annual report, quarterly reports, current reports, proxy statements, section 16 reports and other information (and any amendments thereto) as soon as practicable after filing or furnishing the material to the SEC, in addition to our Corporate Governance Guidelines, codes of ethics and the charters of the Audit, Compensation, Executive, Finance, Governance and Nominating, Public Policy and Safety and Environmental Committees.  These materials also may be requested at no cost by telephone at (866) 814-6512 or by mail at: Massey Energy Company, Post Office Box 26765, Richmond, Virginia 23261, Attention: Investor Relations.

 
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Executive Overview

We operate coal mines and processing facilities in Central Appalachia, which generate revenues and cash flow through the mining, processing and selling of steam and metallurgical grade coal, primarily of a low sulfur content.  We also generate income and cash flow through other coal-related businesses, including the management of material handling facilities.  Other revenue is obtained from royalties, rentals, gas well revenues, gains on the sale or exchange of non-strategic assets and miscellaneous income.  

We reported a net loss for the third quarter of 2010, of $41.4 million, or $0.41 loss per share, compared to net income of $16.5 million, or $0.19 income per share, for the third quarter of 2009.  The results of the third quarter of 2010 were negatively impacted by an additional $14.5 million pre-tax expense for ongoing investigation costs related to the Upper Big Branch (“UBB”) mine tragedy (see Notes 5, 10 and 16 to the Notes to Condensed Consolidated Financial Statements for further discussion), and a loss on derivative instruments of $2.2 million.  Third quarter 2009 net income included a $24.9 million pre-tax non-cash gain on an exchange of coal reserves and other assets and a loss on derivative instruments of $4.8 million.

Produced tons sold were 9.9 million in the third quarter of 2010, compared to 8.7 million in the third quarter of 2009. We produced 9.4 million and 8.8 million tons in the third quarters of 2010 and 2009, respectively.  Shipments of industrial and utility coal were up 29% and 18%, respectively, while shipments of metallurgical coal were down 5%.  Exports remained the same at 1.4 million tons for both the third quarters of 2010 and 2009.

During the third quarter of 2010, Produced coal revenue increased by 31% compared to the third quarter of 2009, reflecting improved pricing for utility coal and higher shipments of utility and industrial coal in 2010, compared to the third quarter of 2009.  Our average Produced coal revenue per ton sold in the third quarter of 2010 increased to $71.24 compared to $61.79 in the third quarter of 2009, primarily due to increases in the average per ton sales price for metallurgical coal of 30% and utility coal of 16% during the third quarter of 2010, compared to the third quarter of 2009.

Our Average cash cost per ton sold (see Note 1 below for non-GAAP financial measure) was $62.50, compared to $49.81 in the previous year’s third quarter (2010 Average cash cost per ton is calculated exclusive of UBB related charges).  The increase was due largely to lower productivity attributable to discrete geologic conditions, increased regulatory enforcement actions and related temporary shutdowns, increased labor turnover rates, higher repairs and supplies expenses, and a higher percentage of underground mine production, which has a higher per ton cost than surface mining.

On April 5, 2010, an accident occurred at the Upper Big Branch mine of our Performance resource group, tragically resulting in the deaths of 29 miners and seriously injuring two miners.  The Federal Mine Safety and Health Administration (“MSHA”) and the State of West Virginia are conducting a joint investigation into the cause of the accident.  We also have commenced our own investigation.  We believe these investigations will continue for the foreseeable future, and we cannot provide any assurance as to their outcome, including whether we become subject to possible civil penalties or enforcement actions.  In order to accommodate these investigations, the mine will continue to be closed for an extended period of time, the length of which we cannot predict at this time.  It is also possible that we may decide or be required by regulators to permanently close this mine.

We have recorded a $78 million liability in Other current liabilities at September 30, 2010, which represents our best estimate of the probable loss related to potential future litigation settlements associated with the UBB tragedy.  Two of the families have filed wrongful death suits against us, while seven families have signed agreements to settle their claims (three of which have been finalized after receiving the required judicial approval).  Insurance recoveries related to our general liability insurance policy that are deemed probable and that are reasonably estimable have been recognized in the Condensed Consolidated Statements of Income to the extent of the related losses.  Such recognized recoveries for litigation settlements associated with the UBB tragedy totaled $78 million and are includ ed in Trade and other accounts receivable at September 30, 2010.

As a result of the April 5, 2010 tragedy at UBB, MSHA significantly increased regulatory enforcement in our mines.  The increased regulatory enforcement had a significant negative impact our productivity and operating results for the third quarter of 2010.  In total, 450 shifts were lost during the quarter due to regulatory issues; nearly
 
26 
 
30 percent of which were due to delays in MSHA’s approval process for ventilation or other mine plan changes.  We estimate that the lost shifts reduced production by approximately 230,000 tons.  If MSHA continues to order certain of our mines to be temporarily closed or permanently closes such mines, our ability to meet our customers’ demands could be adversely affected.

In September 2010, MSHA revised the federal standard for the incombustible content of coal dust, rock dust and other dust combined in coal mines. The revised standard requires us to increase to at least 80% (an increase from 65%) the incombustible content of the coal dust, rock dust, and other dust combined in all accessible areas of underground coal mines. The revised standard is effective for new mining as of October 7, 2010, and for previously mined areas by November 22, 2010. We expect our cost of mining to increase as we comply with the revised standard for additional rock-dusting materials, equipment and labor.
___________________
Note 1: Average cash cost per ton is calculated as the Cost of produced coal revenue (excluding Selling, general and administrative expense (“SG&A”), Depreciation, depletion and amortization (“DD&A”) and UBB related charges) divided by the number of produced tons sold.  In 2009, in order to conform more closely to common industry reporting practices, we changed our calculation of cash cost to exclude SG&A expense.  This change has been reflected in the presentation of data for both the current and comparative past reporting periods in this report. Although Average cash cost per ton is not a measure of performance calculated in accordance with GAAP, management believes that it is useful to investors in evaluating us because it is widely used in the coal industry as a measure to evaluat e a company’s control over its cash costs. Average cash cost per ton should not be considered in isolation or as a substitute for measures of performance in accordance with GAAP. In addition, because Average cash cost per ton is not calculated identically by all companies, the presentation here may not be comparable to other similarly titled measures of other companies. The table below reconciles the GAAP measure of Total costs and expenses to Average cash cost per ton.

   
Three Months Ended September 30,
    
Nine Months Ended September 30,
  
   
2010
    
2009
    
2010
    
2009
  
   
(In Millions, Except Per Ton Amounts)
  
Total costs and expenses
   $ 840.6     $ 595.8     $ 2,383.5     $ 1,940.1  
Less: Freight and handling costs
     65.4       52.5       201.2       171.3  
Less: Cost of purchased coal revenue
     26.1       18.4       65.2       39.1  
Less: Depreciation, depletion and
                                
amortization
     92.5       66.3       306.0       206.6  
Less:  Selling, general and administrative
     23.2       21.5       75.8       63.4  
Less: Other expense
     0.7       0.6       7.3       2.0  
Less: Loss (Gain) on derivative
                                
         instruments
     2.2       4.8       (21.8 )     (4.5 )
Less: UBB charge(1)
     13.1       -       77.1       -  
Average cash cost
   $ 617.4     $ 431.7     $ 1,672.7     $ 1,462.2  
Average cash cost per ton
   $ 62.50     $ 49.81     $ 59.31     $ 50.64  
                                 
                                 
(1) The UBB charge is reconciled as follows:
                                
     Three Months Ended              Nine Months Ended          
   
 September 30, 2010
            
September 30, 2010
          
   Expense related to the UBB tragedy
   $ 14.5             $ 143.4          
   Less: Expense included in SG&A
     -               2.7          
   Less: Expense included in DD&A
     1.4               63.6          
       UBB charge included in Costs of
                                
       produced coal revenue
   $ 13.1             $ 77.1          

 
 
27 
 

Results of Operations

Three months ended September 30, 2010 compared to three months ended September 30, 2009

Revenues

   
Three Months Ended
              
   
September 30,
              
               
Increase
    
% Increase
  
   
2010
    
2009
    
(Decrease)
    
(Decrease)
  
   
(In Thousands)
        
Revenues
                        
   Produced coal revenue
   $ 703,652     $ 535,531     $ 168,121       31%  
   Freight and handling revenue
     65,405       52,523       12,882       25%  
   Purchased coal revenue
     28,824       14,570       14,254       98%  
   Other revenue
     12,283       38,936       (26,653 )     (68%)  
Total revenues
   $ 810,164     $ 641,560     $ 168,604       26%  


The following is a breakdown by market served of the changes in produced tons sold and average produced coal revenue per ton sold for the third quarter of 2010, compared to the third quarter of 2009:


   
Three Months Ended
              
   
September 30,
              
               
Increase
    
% Increase
  
   
2010
    
2009
    
(Decrease)
    
(Decrease)
  
   
(In Millions, Except Per Ton Amounts)
        
Produced tons sold:
                        
   Utility
     7.2       6.1       1.1       18%  
   Metallurgical
     1.8       1.9       (0.1 )     (5%)  
   Industrial
     0.9       0.7       0.2       29%  
      Total
     9.9       8.7       1.2       14%  
                                 
Average produced coal revenue per ton sold:
                                
   Utility
   $ 62.37     $ 53.84     $ 8.53       16%  
   Metallurgical
     109.72       84.58       25.14       30%  
   Industrial
     64.94       69.26       (4.32 )     (6%)  
      Weighted average
   $ 71.24     $ 61.79     $ 9.45       15%  

Shipments of industrial and utility coal increased during the third quarter of 2010, compared to the same period in 2009, to meet higher demand in 2010 as economic conditions have improved and the hot summer experienced in the region serviced by our utility customers drew down stockpiles.  The average per ton sales price for utility coal was higher in the third quarter of 2010, compared to the third quarter of 2009, mainly attributable to the addition of higher priced utility coal contracts assumed in the acquisition of Cumberland.  Pricing improved on metallurgical coal sales as demand for this type of coal has improved, especially with respect to exports to Europe and Asia.

Freight and handling revenue increased due to an increase in export tons shipped of 10% in the third quarter of 2010, compared to the same period in 2009.

Purchased coal revenue increased in the third quarter of 2010, compared to the same period in 2009, primarily due to a 57% increase in the amount of purchased tons sold and a significant increase in selling price.  Purchased coal revenue per ton increased to $83.42 during the third quarter of 2010, from $66.25 during the third quarter of 2009, as a result of a change in the mix of purchased coal that included higher priced purchased metallurgical coal shipments during the third quarter of 2010, compared to the third quarter of 2009.

 
 28
 
Other revenue includes refunds on railroad agreements, royalties related to coal lease agreements, gas well revenue, gains on the sale or exchange of non-strategic assets and reserve exchanges, joint venture revenue and other miscellaneous revenue. Other revenue for the third quarter of 2009 includes a pre-tax gain of $24.9 million on the exchange of coal reserves.

Costs

   
Three Months Ended
              
   
September 30,
              
               
Increase
    
% Increase
  
   
2010
    
2009
    
(Decrease)
    
(Decrease)
  
   
(In Thousands)
        
Costs and expenses
                        
   Cost of produced coal revenue
   $ 630,456     $ 431,697     $ 198,759       46%  
   Freight and handling costs
     65,405       52,523       12,882       25%  
   Cost of purchased coal revenue
     26,116       18,366       7,750       42%  
   Depreciation, depletion and amortization,
                                
   applicable to:
                                
      Cost of produced coal revenue
     76,839       66,105       10,734       16%  
      Selling, general and administrative
     15,725       164       15,561    
    nm
  
   Selling, general and administrative
     23,153       21,549       1,604       7%  
   Other expense
     718       608       110       18%  
   Loss (Gain) on derivative instruments
     2,209       4,765       (2,556 )     (54%)  
Total costs and expenses
   $ 840,621     $ 595,777     $ 244,844       41%  


Cost of produced coal revenue increased primarily due to a higher volume of produced tons sold to 9.9 million in the third quarter of 2010, from 8.7 million in the third quarter of 2009.  Additional factors leading to the increase were lower productivity attributable to discrete geologic conditions, increased regulatory enforcement actions and related temporary shutdowns, increased labor turnover rates, higher repairs and supplies expenses, and a higher percentage of underground mine production, which has a higher per ton cost than surface mining.  The UBB tragedy contributed $13.1 million to our Cost of produced coal revenue.

Freight and handling costs increased due to an increase in export tons shipped of 10% in the third quarter of 2010, compared to the same period in 2009.

Cost of purchased coal revenue increased in the third quarter of 2010, compared to the same period in 2009, primarily due to a 57% increase in the amount of purchased tons sold.  Cost of purchased coal revenue per ton decreased to $78.52 during the third quarter of 2010, from $85.78 during the third quarter of 2009.

Depreciation, depletion and amortization applicable to Cost of produced coal revenue increased in the third quarter of 2010, compared to the same period in 2009, primarily due to the addition of the operations from the Cumberland acquisition.  Depreciation, depletion and amortization applicable to Selling, general and administrative increased in the third quarter of 2010, compared to the same period in 2009 as a result of amortization expense recorded on coal sales contracts acquired in April 2010 as part of the acquisition of Cumberland (see Note 6 to the Notes to Condensed Consolidated Financial Statements for further discussion).

Selling, general and administrative expense was higher in the third quarter of 2010, compared to the third quarter of 2009, primarily due to increased advertising and public relations expenses.

Loss (Gain) on derivative instruments for the third quarter of 2010, represents a loss on derivative instruments of $2.2 million ($11.0 million of unrealized losses primarily due to certain contracts identified that no longer qualified for the normal purchase normal sale (“NPNS”) exception that are now accounted for at fair value plus $8.8 million of realized gains due to settlements on existing purchase and sales contracts).  The third quarter of 2009 results included a loss on derivative instruments of $4.8 million ($2.4 million of unrealized losses primarily due to
 
29
 
certain contracts identified that no longer qualified for the NPNS exception that are now accounted for at fair value plus $2.4 million of realized losses due to settlements on existing purchase and sales contracts).  See Note 13 to the Notes to Condensed Consolidated Financial Statements for further discussion.

Interest Income

Interest income decreased for the third quarter of 2010, compared to the same period in 2009, as a result of a reduction in interest earned on money market funds during the third quarter of 2010, compared to the same period in 2009.

Interest Expense

Interest expense includes $5.0 million and $4.8 million of non-cash interest expense for the amortization of the discount of our 3.25% Notes for the third quarters of 2010 and 2009, respectively (see Note 7 to the Notes to Condensed Consolidated Financial Statements for further discussion).

Income Taxes

Our effective tax rate is sensitive to changes in estimates of annual pre-tax earnings and percentage depletion.  The increase in the effective tax rate from the third quarter of 2009, to the third quarter of 2010, is primarily the result of differences in pre-tax income, the impact of percentage depletion and projected changes in deferred taxable and deductible differences.  The 2009 income tax rate was impacted by favorable adjustments in connection with the election to forego bonus depreciation and claim a refund for alternative minimum tax credits.

Nine months ended September 30, 2010 compared to nine months ended September 30, 2009

Revenues

   
Nine Months Ended
              
   
September 30,
              
               
Increase
    
% Increase
  
   
2010
    
2009
    
(Decrease)
    
(Decrease)
  
   
(In Thousands)
        
Revenues
                        
   Produced coal revenue
   $ 1,968,514     $ 1,819,777     $ 148,737       8%  
   Freight and handling revenue
     201,159       171,253       29,906       17%  
   Purchased coal revenue
     70,405       43,741       26,664       61%  
   Other revenue
     68,873       72,504       (3,631 )     (5%)  
Total revenues
   $ 2,308,951     $ 2,107,275     $ 201,676       10%  


 
  30
 
The following is a breakdown by market served of the changes in produced tons sold and average produced coal revenue per ton sold for the first nine months of 2010, compared to the first nine months of 2009:


   
Nine Months Ended
              
   
September 30,
              
               
Increase
    
% Increase
  
   
2010
    
2009
    
(Decrease)
    
(Decrease)
  
   
(In Millions, Except Per Ton Amounts)
        
Produced tons sold:
                        
   Utility
     19.4       21.4       (2.0 )     (9%)  
   Metallurgical
     6.3       5.5       0.8       15%  
   Industrial
     2.5       2.0       0.5       25%  
      Total
     28.2       28.9       (0.7 )     (2%)  
                                 
Average produced coal revenue per ton sold:
                                
   Utility
   $ 61.05     $ 53.74     $ 7.31       14%  
   Metallurgical
     97.64       97.60       0.04       0%  
   Industrial
     67.72       68.25       (0.53 )     (1%)  
      Weighted average
   $ 69.80     $ 63.02     $ 6.78       11%  

Shipments of metallurgical and industrial coal increased during the first nine months of 2010, compared to the same period in 2009 to meet higher demand in 2010 as economic conditions have improved.  Shipments of utility coal decreased in the first nine months of 2010, compared to the same period in 2009, primarily due to lower customer demand in the third quarter as electric utilities continued to draw down from previously high stockpile levels.  The average per ton sales price for utility coal was higher in the first nine months of 2010, compared to the first nine months of 2009, mainly attributable to the addition of higher priced utility coal contracts assumed in the acquisition of Cumberland.

Freight and handling revenue increased due to metallurgical export coal increased to 4.2 million tons shipped in the first nine months of 2010, from 3.5 million tons shipped in the first nine months of 2009.  Overall revenue per ton for export tons shipped increased to $94.50 during the first nine months of 2010, from $83.61 during the first nine months of 2009.

Purchased coal revenue increased in the first nine months of 2010, compared to the same period in 2009, primarily due to a 42% increase in the amount of purchased tons sold and a significant increase in selling price.  Purchased coal revenue per ton increased to $75.84 during the first nine months of 2010, from $66.89 during the first nine months of 2009, as a result of a change in the mix of purchased coal that included more purchased metallurgical coal shipments during the first nine months of 2010, compared to the first nine months of 2009.

Other revenue includes refunds on railroad agreements, royalties related to coal lease agreements, gas well revenue, gains on the sale of non-strategic assets and reserve exchanges, joint venture revenue and other miscellaneous revenue. Other revenue for the first nine months of 2010 includes $9.7 million (pre-tax) from the settlement of certain claims against a service provider, $7.2 million (pre-tax) related to the sale of a claim in a customer bankruptcy proceeding, and a pre-tax gain of $6.9 million on exchanges of coal reserves.  Other revenue for the first nine months of 2009 includes a pre-tax gain of $32.0 million on the sale and exchange of coal reserve interests and other assets.

 
31 
 

Costs

 
Nine Months Ended
        
 
September 30,
        
         
Increase
  
% Increase
 
2010
  
2009
  
(Decrease)
  
(Decrease)
 
(In Thousands)
    
Costs and expenses
              
   Cost of produced coal revenue
 $1,749,822
  
 $1,462,263
  
 $287,559
  
20%
   Freight and handling costs
 201,159
  
 171,253
  
 29,906
  
17%
   Cost of purchased coal revenue
 65,202
  
 39,061
  
 26,141
  
67%
   Depreciation, depletion and amortization,
              
   applicable to:
              
      Cost of produced coal revenue
 273,962
  
 204,524
  
 69,438
  
34%
      Selling, general and administrative
 31,969
  
 2,025
  
 29,944
  
nm
   Selling, general and administrative
 75,788
  
 63,420
  
 12,368
  
20%
   Other expense
 7,311
  
 1,970
  
 5,341
  
nm
   Gain on derivative instruments
 (21,795)
  
 (4,479)
  
 (17,316)
  
nm
Total costs and expenses
 $2,383,418
  
 $1,940,037
  
 $443,381
  
23%


Cost of produced coal revenue increased during the first nine months of 2010, compared to the same period in 2009.  Factors leading to the increase were lower productivity attributable to discrete geologic conditions, increased regulatory enforcement actions and related temporary shutdowns, increased labor turnover rates, higher repairs and supplies expenses, and a higher percentage of underground mine production, which has a higher per ton cost than surface mining.  The UBB tragedy contributed $77.1 million to our Cost of produced coal revenue.

Freight and handling costs increased due to metallurgical export coal increased to 4.2 million tons shipped in the first nine months of 2010, from 3.5 million tons shipped in the first nine months of 2009.

Cost of purchased coal revenue increased in the first nine months of 2010, compared to the same period in 2009, primarily due to a 42% increase in the amount of purchased tons sold.  Cost of purchased coal revenue per ton increased to $67.02 during the first nine months of 2010, from $66.07 during the first nine months of 2009.

Depreciation, depletion and amortization applicable to Cost of produced coal revenue increased in the first nine months of 2010, compared to the same period in 2009, due to the $63.6 million impairment of assets at the UBB mine (see Note 5 to the Notes to Condensed Consolidated Financial Statements for further discussion) and the addition of the operations from the Cumberland acquisition.  Depreciation, depletion and amortization applicable to Selling, general and administrative increased in the first nine months of 2010, compared to the same period in 2009 as a result of amortization expense recorded on coal sales contracts acquired in April 2010 as part of the acquisition of Cumberland (see Note 6 to the Notes to Condensed Consolidated Financial Statements for further discussion).

Selling, general and administrative expense increased due to an $8.5 million charge recorded in relation to a customer pricing dispute, $2.7 million related to the UBB tragedy, and increased advertising and public relations expenses.

Gain on derivative instruments for the first nine months of 2010, represents a gain on derivative instruments of $21.8 million ($5.7 million of unrealized losses primarily due to certain contracts identified that no longer qualified for the NPNS exception that are now accounted for at fair value plus $27.5 million of realized gains due to settlements on existing purchase and sales contracts).  The third quarter of 2009 results included a gain on derivative instruments of $4.5 million ($22.6 million of unrealized gains primarily due to certain contracts identified that no longer qualified for the NPNS exception that are now accounted for at fair value plus $18.1 million of realized losses due to settlements on existing purchase and sales contracts).  See Note 13 to the Notes to Condensed Consolidated Financial State ments for further discussion.
 
32 
 
Interest Income

Interest income decreased for the first nine months of 2010, compared to the same period in 2009, as a result of $8.5 million in interest received related to black lung excise tax refunds during the first nine months of 2009. Additionally, due to historically low interest rates, we experienced a significant reduction in interest earned on money market funds during the first nine months of 2010, compared to the same period in 2009.

Interest Expense

Interest expense includes $14.8 million and $13.9 million of non-cash interest expense for the amortization of the discount of our 3.25% Notes for the first nine months of 2010 and 2009, respectively (see Note 7 to the Notes to Condensed Consolidated Financial Statements for further discussion).

Gain on short-term investment

Gain on short-term investment reflects the difference between our book value in the Primary Fund and total distributions received from the fund.  At December 31, 2009, our investment in the Primary Fund was $10.9 million, net of a $6.5 million write-down recorded in 2008.  During the first nine months of 2010, we received distributions from the Primary Fund in the amount of $15.6 million. Consequently, we recorded a $4.7 million gain.

Income Taxes

Our effective tax rate is sensitive to changes in estimates of annual pre-tax earnings and percentage depletion. The increase in the effective tax rate from the first nine months of 2009, to the first nine months of 2010, is primarily the result of differences in pre-tax income, the impact of percentage depletion and projected changes in deferred taxable and deductible differences.  The UBB charges of $143.4 million impacted the 2010 income tax rate with a $94.7 million benefit during the first nine months of 2010.  Also impacting the 2010 income tax rate was a $2.6 million charge related to the reduction in the tax benefit available to us as a result of the PPACA signed into law in March 2010.  Our income tax benefit during the first nine months of 2009 was impacted by favorable adjustments in connection with the election to forego bonus depreciation and claim a refund for alternative minimum tax credits.

Liquidity and Capital Resources

At September 30, 2010, our available liquidity was $571.0 million, comprised of Cash and cash equivalents of $477.0 million and $94.0 million of availability from our asset-based revolving credit facility (“ABL”).  Our total debt-to-book capitalization ratio was 40.9% at September 30, 2010.

Our Debt was comprised of the following:

   
September 30, 2010
    
December 31, 2009
  
   
(In Thousands)
  
6.875% senior notes due 2013, net of discount
            
     of $2,727 and $3,273, respectively
   $ 757,273     $ 756,727  
3.25% convertible senior notes due 2015, net of discount
                
     of $117,852 and $132,628, respectively
     541,211       526,435  
6.625% senior notes due 2010
     -       21,949  
2.25% convertible senior notes due 2024
     9,647       9,647  
Capital lease obligations
     3,144       4,328  
          Total debt
     1,311,275       1,319,086  
          Amounts due within one year
     (3,077 )     (23,531 )
          Total long-term debt
   $ 1,308,198     $ 1,295,555  

We believe that during the third quarter of 2010 we were, and currently are, in compliance with our debt covenants.
 
  33
 
6.625% Notes

During January 2010, we redeemed at par the remaining $21.9 million of our 6.625% senior notes due 2010.

Authorized Common Stock

On October 6, 2010, at a Special Meeting of Stockholders, our stockholders approved an increase of authorized shares of Common Stock from 150,000,000 to 300,000,000 shares.

Common Stock Issuance

On March 23, 2010, we completed a registered underwritten public offering of 9,775,000 shares of our Common Stock at a public offering price of $49.75 per share, resulting in proceeds to us of $466.8 million, net of fees.  In April 2010, we used the net proceeds of this offering and 6,519,034 shares of Common Stock (fair valued at $289.5 million on the day of the acquisition) to fund a portion of the consideration for the acquisition of Cumberland.  See Note 2 to the Notes to Condensed Consolidated Financial Statements for a more complete discussion.

Common Stock Repurchases

During the second quarter of 2010, we repurchased 861,439 shares of Common Stock at an average price of $36.92, for a total cost of $31.8 million.  The Common Stock was repurchased under a stock repurchase program (the “Repurchase Program”) authorized by our Board of Directors on November 14, 2005, authorizing us to repurchase shares of Common Stock from time to time up to an aggregate amount not to exceed $500 million, as market conditions warrant and existing covenants permit.  Prior to this share repurchase, we had $420 million available under the 2005 authorization.  We did not repurchase any shares in the third quarter of 2010.  Shares repurchased in 2010 under the program have been recorded as Treasury stock in the Condensed Consolidated Balance Sheet.

Asset-Based Credit Facility

On November 8, 2010, we entered into an amended and restated asset-based revolving credit agreement, which provides for available borrowings, including letters of credit, of up to $200 million, depending on the level of eligible inventory and accounts receivable.  Subject to current conditions, at any time prior to maturity, the Borrower may elect to increase the size of the facility up to $250 million.  The previous asset-based revolving credit agreement provided for available borrowings, including letters of credit, of up to $175 million, depending on the level of eligible inventory and accounts receivable.  In addition, we extended the facility’s maturity to May 2015.  As of September 30, 2010, there were $76.4 million of letters of credit issued and there were no outstanding borrowings under this facility.

Cash Flow

Net cash provided by operating activities was $268.1 million for the first nine months of 2010, compared to $232.1 million for the first nine months of 2009.  Cash provided by operating activities reflects Net income adjusted for non-cash charges and changes in working capital requirements.

Net cash utilized by investing activities was $880.3 million and $183.0 million for the first nine months of 2010 and 2009, respectively.  The cash used in investing activities reflects capital expenditures in the amount of $278.5 million and $223.0 million for the first nine months of 2010 and 2009, respectively.  These capital expenditures are for replacement of mining equipment, the expansion of mining and shipping capacity, projects to improve the efficiency of mining operations and for compliance with safety regulations.  The recent acquisition of Cumberland resulted in a net cash outflow of $630.0 million (net of cash acquired of $14.7 million).  Additionally, the first nine months of 2010 and 2009 included $3.0 million and $15.7 million, respectively, of proceeds provided by the sale of a ssets.  The first nine months of 2010 also includes $9.6 million of proceeds from insurance recoveries.

 
34
 
Net cash provided and (utilized) by financing activities was $423.5 million and $16.1 million for the first nine months of 2010 and 2009, respectively.  Financing activities for the first nine months of 2010 primarily reflects a registered underwritten public equity offering, resulting in proceeds to us of $466.8 million, net of fees, partially offset by the repayment of our 6.625% Notes of $21.9 million.  During the first nine months of 2010, we repurchased shares of Common Stock for $31.8 million.  Financing activities for the first nine months of 2010 and 2009 also reflects payments of $17.4 million and $15.3 million, respectively, for the regular quarterly dividend on shares of Common Stock.  Members exe rcising stock options during the first nine months of 2010 and 2009 resulted in cash inflows of $12.0 million and $1.2 million, respectively.  Proceeds from sale-leaseback transactions resulted in cash inflows of $16.5 million for the first nine months of 2010.

We believe that cash on hand, cash generated from operations and our borrowing capacity will be sufficient to meet our working capital requirements, scheduled debt payments, potential share repurchases and debt repurchases, anticipated dividend payments, expected settlements of outstanding litigation, anticipated capital expenditures and costs related to the UBB tragedy (see Notes 5, 10 and 16 to the Notes to Condensed Consolidated Financial Statements), including any increased premiums for insurance, any claims that may be asserted against us and other expenses that are not covered, in whole or in part, by our insurance policies, for at least the next twelve months.  Nevertheless, our ability to satisfy our debt service obligations, repurchase shares and debt, pay dividends, pay settlements or judgments in respect of pendin g litigation, fund planned capital expenditures or pay the costs related to the UBB tragedy, will substantially depend upon our future operating performance, which will be affected by prevailing economic conditions in the coal industry, debt covenants and financial, business and other factors, some of which are beyond our control.

We frequently evaluate potential acquisitions.  As a result of the cash needs we have described above and possible acquisition opportunities, in the future we may consider a variety of financing sources, including debt or equity financing.  Currently, other than our ABL, we have no commitments for any additional financing.  We cannot be certain that we will be able to obtain additional financing on terms that we find acceptable, if at all, through the issuance of equity securities or the incurrence of additional debt.  Additional equity financing may dilute our stockholders, and debt financing, if available, may among other things, restrict our ability to repurchase shares of Common Stock, declare and pay dividends and raise future capital.  If we are unable to obtain additional needed financing, it may prohibit us from making acquisitions, capital expenditures and/or investments, which could materially and adversely affect our prospects for long-term growth.

Debt Ratings
 
Moody’s Investors Service (“Moody’s”) and Standard & Poor’s Rating Services (“S&P”) rate our long-term debt.  On October 19, 2010, the outlook for our S&P ratings was changed from Negative to Watch Developing in response to a Wall Street Journal article saying that Massey is considering strategic options.  As of November 5, 2010, the outlook for our Moody’s ratings was Stable.

A significant downgrade in our debt ratings could adversely affect our borrowing capacity and costs, the costs of maintaining certain contractual relationships and future financings.

Certain Trends and Uncertainties

In addition to trends and uncertainties set forth below, please refer to “Certain Trends and Uncertainties” of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operation, of our Annual Report on Form 10-K for the year ended December 31, 2009 and our Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2010, and June 30, 2010, for a discussion of certain trends and uncertainties that may impact our business.

Increased regulatory enforcement as a result of the tragedy at UBB has had and may continue to have a negative impact on our business.

As a result of the April 5, 2010 UBB tragedy, MSHA has significantly increased regulatory enforcement in our mines.  The increased regulatory enforcement significantly impacted our productivity and operating results for the second and third quarters of 2010.  If MSHA continues to order certain of our mines to be temporarily closed or
 
 35
 
permanently closes such mines, our ability to meet our customers’ demands could be adversely affected, which would adversely affect our financial position, results of operations and cash flows.

We may be required to recognize additional charges in our financial results for losses related to the tragedy at UBB.

As a result of the UBB tragedy on April 5, 2010, we have recognized a pre-tax charge of $143.4 million, $14.5 million of which was reported as part of our financial earnings for the third quarter of 2010.  This charge relates to the benefits being provided to the families of the fallen miners, costs associated with the rescue and recovery efforts, an impairment charge for the write-off of equipment, mine development and longwall panel costs impacted by the tragedy, possible legal and other contingencies.  Given the uncertainty of the outcome of current investigations, including whether we become subject to possible civil penalties or enforcement actions, it is possible that the total costs incurred related to this tragedy could exceed our current estimates.  We continue to evaluate the impact of this even t on our business, and these reviews may result in future additional charges and costs, which would adversely affect our business, financial position, results of operations and cash flows.

Federal, state and local laws and government regulations applicable to mining operations may increase our costs.

We incur substantial costs and liabilities under increasingly strict federal, state and local environmental, health and safety and endangered species laws, regulations and enforcement policies.  Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of cleanup and site restoration costs and liens, the issuance of injunctions to limit or cease operations, the suspension or revocation of permits and other enforcement measures that could have the effect of limiting production from our operations.  In this regard, MSHA and the State of West Virginia have begun a joint investigation into the cause of the April 5, 2010 accident at our UBB mine at our Performance resource group in West Virginia.  The costs of compliance with applicable regulations and liabilities assessed for compliance failure could have a material adverse impact on our cash flows, results of operations or financial condition.

New legislation and new regulations, including legislation and regulations resulting from the April 5, 2010 accident at our UBB mine, may be adopted which could materially adversely affect our mining operations, cost structure or our customers’ ability to use coal.  New legislation and new regulations may also require us, as well as our customers, to significantly change operations or incur increased costs.  The United States Environmental Protection Agency has undertaken broad initiatives to increase compliance with emissions standards and to provide incentives to our customers to decrease their emissions, often by switching to an alternative fuel source or by installing scrubbers or other expensive emissions reduction equipment at their coal-fired plants.

Off-Balance Sheet Arrangements

In the normal course of business, we are a party to certain off-balance sheet arrangements including guarantees, operating leases, indemnifications, and financial instruments with off-balance sheet risk, such as bank letters of credit and performance or surety bonds. Liabilities related to these arrangements are not reflected in the Condensed Consolidated Balance Sheets, and, except for the operating leases, we do not expect any material impact on our cash flows, results of operations or financial condition to result from these off-balance sheet arrangements.

From time to time we use bank letters of credit to secure our obligations for workers’ compensation programs, various insurance contracts and other obligations. At September 30, 2010, we had $134.6 million of letters of credit outstanding of which $58.2 million were collateralized by $59.4 million of cash deposited in restricted, interest bearing accounts pledged to issuing banks and $76.4 million were issued under our ABL.  No claims were outstanding against those letters of credit as of September 30, 2010.

We use surety bonds to secure reclamation, workers’ compensation, wage payments and other miscellaneous obligations.  As of September 30, 2010, we had $355.3 million of outstanding surety bonds.  These bonds were in place to secure obligations as follows: post-mining reclamation bonds of $334.2 million and other miscellaneous obligation bonds of $21.1 million.  Outstanding surety bonds of $46.1 million are secured with letters of credit. 
 
 
36 
 
Generally, the availability and market terms of surety bonds continue to be challenging.  If we are unable to meet certain financial tests applicable to some of our surety bonds, or to the extent that surety bonds otherwise become unavailable, we would need to replace the surety bonds or seek to secure them with letters of credit, cash deposits, or other suitable forms of collateral.

Critical Accounting Estimates and Assumptions

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect reported amounts.  These estimates and assumptions are based on information available as of the date of the financial statements.  Accounting measurements at interim dates inherently involve greater reliance on estimates than at year-end.  The results of operations for the quarterly period ended September 30, 2010, are not necessarily indicative of results that can be expected for the full year.  Please refer to the section entitled “Critical Accounting Estimates and Assumptions” of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operation of our Annual Report on Form 10-K for the year ended December 31, 2009, and o ur Quarterly Report on Form 10-Q for the quarterly periods ended March 31, 2010, and June 30, 2010, for a discussion of our critical accounting estimates and assumptions.

Recent Accounting Pronouncements

In January 2010, the FASB issued an accounting standard update, amending disclosure requirements related to Fair Value Measurements and Disclosures, as follows:

 
1.
Significant transfers between Level 1 and 2 shall be disclosed separately, including the reasons for the transfers; and
 
2.
Information about purchases, sales, issuances and settlements shall be disclosed separately in the reconciliation of activity in Level 3 fair value measurements.

This accounting standard update is effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances and settlements in the reconciliation of activity in Level 3 fair value measurements, which are effective for interim and annual reporting periods beginning after December 15, 2010.  The initial adoption of this accounting standard update did not have a material impact on our financial position or results of operations and the adoption for disclosures effective for interim and annual reporting periods beginning after December 15, 2010 is not expected to have a material impact on our cash flows, financial position or results of operations.  See Note 14 to the Notes to Condensed Consolidated Financial Statements for more information on ou r Fair Value Measurements and Disclosures.

In April 2010, the FASB issued an accounting standard update, amending disclosure requirements related to income taxes, as a result of the PPACA, which became law on March 23, 2010, and was subsequently amended on March 30, 2010.  Beginning in fiscal year 2014, the tax deduction available to us will be reduced to the extent our drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program.  Because retiree health care liabilities and the related tax impacts are already reflected in our Condensed Consolidated Financial Statements, we are required to recognize the full accounting impact of this accounting standard update in the period in which the PPACA was signed into law.  The total non-cash charge to Income tax expense related to the reduction in the tax benefit was $2.6 million, an d was recorded in the first quarter of 2010.

Item 3:  Quantitative and Qualitative Discussions About Market Risk

In addition to quantitative and qualitative discussions about market risk set forth below, please refer to Item 7A. Quantitative and Qualitative Discussions About Market Risk of our Annual Report on Form 10-K for the year ended December 31, 2009, for a discussion of certain market risk factors, which may impact our business.

 
 37
 
Our derivative contracts that do not qualify for NPNS designation give rise to commodity price risk, which represents the potential gain or loss that can be caused by an adverse change in the price of coal. See Note 13 to the Notes to Condensed Consolidated Financial Statements for further discussion of our derivatives. The outstanding purchase and sales contracts at September 30, 2010, that are accounted for as derivative instruments, are summarized as follows:

           Tons      
   
Price Range
    
Outstanding
  
Delivery Period
  
 
 Purchase Contracts   $56.50 - $67.00       750,000  
10/01/10 - 12/01/11
  
 
 Sales Contracts    $56.25 - $127.00       1,634,250  
10/01/10 - 12/01/11
  


As of September 30, 2010, a hypothetical increase of 10% in the forward market price would result in an additional fair value loss recorded for these derivative instruments of $6.1 million.  A hypothetical decrease of 10% in the forward market price would result in a fair value gain recorded for these derivative instruments of $6.1 million.

Item 4:  Controls and Procedures

Pursuant to Rule 13a-15(b) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we carried out an evaluation, with the participation of our management, including our Chief Executive Officer (“CEO”), who is our principal executive officer, and Chief Financial Officer (“CFO”), who is our principal financial officer, of the effectiveness of our disclosure controls and procedures (as defined under Rule 13a-15(e) under the Exchange Act) as of the end of the period covered by this report. Based upon that evaluation, our CEO and CFO concluded that our disclosure controls and procedures are effective to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act, is recorded, processed, summarized and reported, within the time pe riods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.

There has been no change in our internal control over financial reporting during the three months ended September 30, 2010, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

In reliance on guidance set forth in Question 3 of a “Frequently Asked Questions” interpretative release issued by the Staff of the SEC’s Office of the Chief Accountant and the Division of Corporation Finance in September 2004, as revised on September 24, 2007, regarding Securities Exchange Act Release No. 34-47986, Management’s Report on Internal Control Over Financial Reporting and Certification of Disclosure in Exchange Act Periodic Reports, our management determined that it would exclude the business of Cumberland from the scope of its assessment of changes in internal control over financial reporting for the three months ended September 30, 2010.  The reason for this exclusion is that we acquired Cumberland in April 2010 and it was not poss ible for management to conduct an assessment of internal control over financial reporting in the period between the date the acquisition was completed and the date of management’s assessment.  Accordingly, management excluded Cumberland from its assessment of changes to internal control over financial reporting during the quarter ended September 30, 2010.  Cumberland will be included in management’s assessment of internal control over financial reporting starting no later than our annual assessment for the fiscal year beginning January 1, 2011.

Our management, including our CEO and CFO, does not expect that our disclosure controls and procedures or our internal control over financial reporting will prevent all errors and all fraud.  A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met.  Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs.  Because of the inherent limitations in all control systems, no evaluation of the controls can provide absolute assurance that all control issues and instances of fraud, if any, have been detected.

 
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PART II: OTHER INFORMATION

Item 1. Legal Proceedings

Derivative Litigation

A number of purported stockholders have brought lawsuits derivatively on behalf of Massey Energy Company (“Massey”), in West Virginia and Delaware state courts, in connection with the April 5, 2010, tragedy at UBB and related claims.

West Virginia

On April 15, 2010, purported Massey stockholder, Manville Personal Injury Settlement Trust (“Manville”), filed a derivative lawsuit in the Circuit Court of Kanawha County, alleging that certain current and former members of the Board of Directors and Massey officers breached their fiduciary duties by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB (the “Manville Action”).  Manville seeks (1) a declaration that defendants have violated their fiduciary duties to Massey; (2) an award against all defendants for the amount of damages sustained by Massey as a result of any breach of fiduciary duties; and (3) an award to Manville for costs and disbursements of the action.  On June 7, 2010, Manville—now joined by two additional st ockholders, the California State Teachers’ Retirement System and Amalgamated Bank, as Trustee for the Longview Collection Investment Funds (together with Manville, the “Manville Plaintiffs”)—amended its complaint, adding additional allegations relating to the defendants’  alleged breaches of fiduciary duties.

On April 21, 2010, purported Massey stockholder, International Union of Operating Engineers Pension Fund of Eastern Pennsylvania and Delaware (“IUOE”), filed a derivative lawsuit in the Circuit Court of Wyoming County, alleging that certain current and former members of the Board of Directors breached their fiduciary duties by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in failures to comply with applicable health, safety and environmental laws and regulations (the “West Virginia IUOE Action”).  IUOE seeks (1) a declaration that defendants breached their fiduciary duties; (2) compensatory and consequential damages to Massey; and (3) an award to IUOE of fees and expenses incurred in pursuing this action.  As described below, the West Virginia IUOE Action has been dismissed without prejudice and refiled in Delaware Chancery Court.

    On April 22, 2010, purported Massey stockholder, Philip R. Arlia (“Arlia”), filed a derivative lawsuit in the Circuit Court of Raleigh County, alleging that certain current and former members of the Board of Directors and Massey officers breached their fiduciary duties, committed gross mismanagement and abused their abilities to control Massey by (1) failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB, fines against Massey for safety-related violations and lawsuits on behalf of injured workers, residents and others; (2) awarding Chairman Blankenship allegedly excessive compensation; (3) making false and misleading statements to Massey’s stockholders; and (4) failing to prevent Chairman Blankenship’s alleged “sharp business practices” (the “Arlia Action” ).  Arlia seeks (1) a declaration that defendants have breached and are breaching their fiduciary duties; (2) an award of compensatory and punitive damages; (3) an award to Arlia of costs and disbursements; (4) an injunction compelling the Board of Directors to cause Massey, its executives and managers not to violate applicable safety and environmental laws, rules and regulations; and (5) the appointment of an independent corporate monitor for the development and implementation of safety and environmental compliance protocols.  As described below, the Arlia Action has been consolidated with the Manville Action.

On April 23, 2010, purported Massey stockholder, Louisiana Municipal Police Employees Retirement System (“LAMPERS”), filed a derivative lawsuit in the Circuit Court of Wyoming County, alleging that certain current and former members of the Board of Directors and Massey officers breached their fiduciary duties by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB (the “West Virginia LAMPERS Action”).  LAMPERS seeks (1) an award of damages sustained by the Company as a result of defendants’ breaches of fiduciary duties and (2) an award to LAMPERS of the costs and disbursements of the action.  As described below, the West Virginia LAMPERS Action has been dismissed without prejudice and LAMPERS has joined in IUOE’s refiled suit in Delaware Chancery Court.
 
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On April 27, 2010, purported Massey stockholder, Brian Lynch (“Lynch”), filed a derivative lawsuit in the Circuit Court of Raleigh County, alleging that certain current and former members of the Board of Directors and Massey officers breached their fiduciary duties, wasted corporate assets and unjustly enriched themselves by (1) failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB and systematic violations of safety and environmental rules and regulations; (2) making false and misleading statements to Massey’s stockholders; and (3) accepting compensation while breaching their fiduciary duties (the “Lynch Action”).  Lynch seeks (1) an award for all damages sustained as a result of defendants’ various alleged breaches of fiduciary du ty; (2) an order requiring Chairman Blankenship to step down as Chairman and CEO, directing Massey to separate position of Chairman and CEO and directing Massey to take certain actions to improve its internal controls relating to worker safety; (3) equitable and/or injunctive relief restricting defendants’ assets so as to assure that plaintiff has an effective remedy; (4) disgorgement of all compensation paid by Massey to defendants; and (5) an award of fees, costs and expenses to Lynch.  As described below, the Lynch Action has been consolidated with the Manville Action.

On May 13, 2010, the defendants in the Manville Action (the “Manville Defendants”) filed a Joint Motion to Transfer and Consolidate, requesting that the Circuit Court of Kanawha County transfer the West Virginia IUOE, Arlia, West Virginia LAMPERS and Lynch Actions to the Circuit Court of Kanawha County and consolidate all five actions before it for all purposes. On June 24, 2010, the Circuit Court of Wyoming County ordered that the West Virginia IUOE and West Virginia LAMPERS Actions be dismissed without prejudice, at the request of IUOE and LAMPERS, respectively.  On July 1, 2010, the Circuit Court of Kanawha County granted the Manville Defendants’ Joint Motion to Transfer and Consolidate and ordered that the Arlia and Lynch Actions be transferred to the Circuit Court of Kanawha County and consolidated wit h the Manville Action for all purposes.  The court’s order did not merge the suits into a single case and, therefore, although the Arlia and Lynch Actions are consolidated with the Manville Action, Arlia and Lynch continue to assert their claims independently.

On July 2, 2010, the Manville Defendants filed a Joint Motion to Stay, requesting that the Circuit Court of Kanawha County stay the consolidated actions pending resolution of a stockholder derivative action brought by the New Jersey Building Laborers Pension Fund (“NJBL”) in the Court of Chancery of the State of Delaware, described below.

On July 19, 2010, the Manville Defendants filed Joint Motions to Dismiss the Manville Action on the grounds that the Manville Plaintiffs did not make a pre-suit demand on the Board of Directors or allege with particularity why such demand was excused and because the Manville Plaintiffs failed to state a claim upon which relief could be granted.  On August 11, 2010, Manville filed a Motion to Consolidate the Manville Action with the contempt proceeding, described below.  The Manville Defendants’ Joint Motion to Stay and Joint Motions to Dismiss are pending before the Circuit Court of Kanawha County.

Delaware

On April 23, 2010, purported stockholder, NJBL, filed a derivative lawsuit in the Chancery Court, alleging that certain current and former members of the Board of Directors breached their fiduciary duties by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in approximately $43 million in fines over the past five years and in the tragedy at UBB (the “NJBL Action”).  NJBL seeks (1) an award of damages against each defendant for restitution, compensatory, punitive and exemplary damages; (2) removal of Chairman Blankenship from office; and (3) an award to NJBL for its costs and disbursements and reasonable allowances for fees.  On July 7, 2010, NJBL amended its complaint, adding additional allegations relating to the defendants’ alleged breaches of fiduciary du ty.

On June 24, 2010, purported stockholder, IUOE, refiled the West Virginia IUOE Action, which it had dismissed without prejudice, in the Chancery Court (the “Delaware IUOE Action”).  The refiled action was similar substantively to the West Virginia IUOE Action.  On July 7, 2010, IUOE—now joined by LAMPERS—amended its complaint, adding additional allegations relating to the defendants’ alleged breaches of fiduciary duties.  The amended complaint seeks (1) an award against defendants for restitution and/or compensatory damages in favor of Massey; (2) removal of Chairman Blankenship from office; and (3) an award to IUOE and LAMPERS of their costs, disbursements and reasonable allowances for fees for counsel and experts.
 
40 
 
On June 29, 2010, purported stockholder, Sandy Taylor (“Taylor”), filed a derivative lawsuit in the Chancery Court (the “Taylor Action”), alleging that certain current and former members of the Board of Directors and officers breached their fiduciary duties and wasted corporate assets by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB.  Taylor seeks (1) a declaration that defendants breached their fiduciary duties; (2) compensatory and consequential damages to Massey; (3) an award to Taylor for the costs and disbursements of the action; (4) an order directing Massey to take all necessary actions to reform and improve its corporate governance and internal procedures with respect to its mining operations; and (5) an order directing Massey t o take all necessary actions to ensure that reasonably suitable safety systems are in force at all Massey mines.
 
On July 2, 2010, Taylor filed a Motion for Consolidation and Appointment of Lead Plaintiff and Lead Counsel, requesting that the court consolidate the Taylor, Delaware IUOE and NJBL Actions and all related subsequent actions; appoint Taylor as lead plaintiff for all actions and appoint Taylor’s counsel as lead counsel and liaison counsel, respectively.  On July 15, 2010, NJBL, IUOE and LAMPERS jointly filed a Motion for Consolidation, Appointment as Lead Plaintiffs and Appointment of Co-Lead Counsel, requesting that the court consolidate the NJBL, Delaware IUOE and Taylor Actions; appoint NJBL, IUOE and LAMPERS as co-lead plaintiffs; and approve NJBL, IUOE and LAMPERS’ counsel as co-lead counsel.

On July 22, 2010, purported stockholder, Helene Hutt (“Hutt”), filed a derivative lawsuit in the Chancery Court (the “Hutt Action”), alleging that certain current and former members of the Board of Directors and officers breached their fiduciary duties by failing to monitor and oversee Massey’s employees, which failure allegedly resulted in the tragedy at UBB.  Hutt seeks (1) an award in favor of Massey for the amount of damages sustained by it as a result of defendants’ alleged breaches of their fiduciary duties; (2) removal of Chairman Blankenship from office; (3) equitable and/or injunctive relief restricting the proceeds of defendants’ trading activities or their other assets to assure that Hutt has an effective remedy; (3) disgorgement of all profits, benefits, and other compens ation obtained by defendants; and (4) an award to Hutt of the costs and disbursements of the action, including reasonable attorneys’ fees. On July 29, 2010, Hutt filed a Motion for Appointment of Lead Plaintiff, Lead Counsel and Liaison Counsel, requesting that the court appoint Hutt as lead plaintiff and appoint her counsel as co-lead counsel and as Delaware liaison counsel for all plaintiffs.  In her motion, Hutt stated that she did not oppose the motions for consolidation filed by Taylor and NJBL, IUOE and LAMPERS.

On September 7, 2010, Taylor withdrew her Motion for Consolidation and Appointment of Lead Plaintiff and Lead Counsel and requested that the court grant NJBL, IUOE and LAMPERS’ Motion for Consolidation, Appointment as Lead Plaintiffs and Appointment of Co-Lead Counsel.

On October 19, 2010, Hutt, Taylor, NJBL, IUOE and LAMPERS informed the court that they had reached an agreement to consolidate the respective actions and submitted a Stipulation and (Proposed) Order of Consolidation for the Chancery Court’s approval.  The Stipulation provides for the consolidation of the actions and the appointment of NJBL, IUOE, LAMPERS and Hutt as Co-Lead Plaintiffs.  The Stipulation further provides that the Co-Lead Plaintiffs must file an Amended and Consolidated Shareholder Derivative Complaint five business days after all Co-Lead Plaintiffs are granted access to certain documents that were produced by Massey to Hutt in response to a demand under Section 220 of the Delaware General Corporation Law.  On October 21, 2010, the Chancery Court approved the Stipulation and ordered th at the actions be consolidated for all purposes.

We and the Defendants have insurance coverage applicable to these matters.  We believe these matters will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.

Federal Class Actions

There are presently two purported class actions brought in connection with alleged violations of the Federal securities laws pending in the United States District Court for the Southern District of West Virginia.

On April 29, 2010, Macomb County Employees’ Retirement System (“Macomb”) filed a purported class action, alleging violations of Section 10(b) of the Exchange Act by certain Massey officers and Section 20(a) of the Exchange Act by these same officers, as well as certain current and former directors in connection with allegedly false and misleading statements regarding Massey’s safety record (the “Macomb Action”).  Macomb seeks (1) an
 
41 
 
award of damages to Macomb and the members of the purported class and (2) an award to Macomb of reasonable costs and attorneys’ fees.

On May 28, 2010, the Firefighters’ Retirement System of Louisiana (“Firefighters”) brought a purported class action, alleging substantially similar violations as Macomb, against the same defendants, as well as another director and officer (the “Firefighters Action”).  Firefighters seeks (1) an award of damages to Firefighters and the members of the purported class and (2) an award to Firefighters of reasonable costs and attorneys’ fees.
 
On June 28, 2010, four purported class members (the Massachusetts Pension Reserves Investment Trust, the MEE Investor Group (a group of three individual stockholders), David Wagner and the Wayne County Employees’ Retirement System) filed separate motions requesting that the court consolidate the Macomb and Firefighters Actions, appoint each purported class member as lead plaintiff and approve each purported class member’s choice of lead counsel.  The MEE Investor Group subsequently withdrew its motion.  The Wayne County Employees’ Retirement System subsequently filed notice stating that it supported the Massachusetts Pension Reserves Investment Trust’s motion, and the court thereafter denied the Wayne County Employees’ Retirement System’s motion as moot. David Wagner’s and the Massachusetts Pension Reserves Investment Trust’s Motions for Consolidation are pending before the court.

We and the Defendants have insurance coverage applicable to these matters.  We believe these matters will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.

Contempt Proceeding

On July 2, 2007, Manville, the same stockholder-plaintiff that initiated the Manville Action described above, filed a complaint in the Circuit Court of Kanawha County, West Virginia alleging that Massey’s Board of Directors and certain of its officers had breached their fiduciary duties by consciously failing to cause Massey’s employees to comply with certain environmental and worker-safety laws and regulations.  On May 20, 2008, the parties executed a Stipulation of Settlement (“Stipulation”), which provided for a broad release of all claims that were or could have been asserted derivatively on behalf of Massey in exchange for, among other things, an agreement that the Board of Directors “shall make a Corporate Social Responsibility report to its stockholders on an annual basis that shall inclu de, among other things, a report on the Company’s environmental and worker safety compliance”.  On June 30, 2008, the Court approved the Stipulation and dismissed Manville’s claims with prejudice (the “Order”).  On April 16, 2010, Manville filed an application in the Circuit Court of Kanawha County, West Virginia requesting that the court initiate civil contempt proceedings against the current members of the Board of Directors in connection with alleged violations of the Order.  Specifically, Manville alleges that the 2009 CSR Report did not contain a sufficient “report on . . . worker safety compliance”.  Manville also requested expedited discovery to determine whether other violations of the Order have occurred.  On April 22, 2010, the court issued an order for a rule to show cause, initiating the contempt proceedings.  On July 13, 2010, the court stayed discovery and set a conference date of August 2 0, 2010, and further ordered that a response to Manville’s application be filed by July 23, 2010.  On July 23, 2010, defendants filed a response to Manville’s application.  On August 3, 2010, Manville filed a reply to defendants’ response to Manville’s application.

On August 11, 2010, Manville filed a Motion to Consolidate the Manville Action, described above, with the contempt proceeding.  On August 18, 2010, defendants filed an opposition to Manville’s Motion to Consolidate.  This motion remains pending before the Circuit Court of Kanawha County.

We and the Defendants have insurance coverage applicable to these matters.  We believe these matters will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.

Other Legal Proceedings

We are parties to a number of other legal proceedings, incident to our normal business activities.  These include, for example, contract disputes, personal injury claims, property damage claims, environmental and safety issues, and employment matters.  While we cannot predict the outcome of any of these proceedings, based on our current estimates we do not believe that any liability arising from these matters individually or in the aggregate should have a material adverse impact upon our consolidated cash flows, results of operations or financial condition.
 
  42
It is possible, however, that the ultimate liabilities in the future with respect to these lawsuits and claims, in the aggregate, may be materially adverse to our cash flows, results of operations or financial condition.

We strive to maintain compliance with all applicable laws at all times. Shortly after the UBB tragedy, the number of citations, orders and notices of violation issued by MSHA and other regulatory agencies increased significantly.  When we receive a citation, order, or notice of violation, we attempt to promptly abate the condition cited, whether or not we agree as to whether the condition constitutes a violation.  Additionally, we either pay the assessed penalties, or, if we dispute the alleged facts behind the violation or the amount of the penalty relative to the violation, we contest the matter.  While these matters have not previously resulted in a material adverse impact on our cash flows, results of operations or financial condition, they could in the future have such an impact.  In addition, if one or more of our operations is placed on a pattern of violations by the regulatory authorities, such designation and the enhanced enforcement regime that accompanies such designation could have a material adverse effect on our cash flows, results of operations or financial condition.
 
We continue to move forward with a great sense of urgency, intensifying our efforts and commitment to significantly reduce the number of infractions received from MSHA and other regulatory agencies.  As an example of our commitment, on October 29, 2010, we idled production at our 92 underground coal producing sections to conduct site specific training at these operations and to reinforce the fact that we expect our miners to follow all safety rules and regulations.  We reviewed past violations at these operations and emphasized best practices to eliminate future violations.  In addition, each mine conducted its own safety inspection and all identified safety infractions were remediated before recommencing production.

    Material developments in legal proceedings affecting us, as previously described in Part I, Item 3. Legal Proceedings, of our Annual Report on Form 10-K for the year ended December 31, 2009, and in subsequently filed interim reports, as they relate to the fiscal quarter ended September 30, 2010, are set forth in Note 16, “Contingencies,” of the Notes to Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q and are incorporated herein by reference.

 Item 1A. Risk Factors

We are subject to a variety of risks, including, but not limited to those referenced under the heading “Certain Trends and Uncertainties” of Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations of this Quarterly Report on Form 10-Q and those referenced herein to other Items contained in our Annual Report on Form 10-K for the year ended December 31, 2009, including Item 1. Business, under the headings “Customers and Coal Contracts,” “Competition,” and “Environmental, Safety and Health Laws and Regulations,” Item 1A. Risk Factors, Item 3. Legal Proceedings and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, under the headings “Critical Accounting Estimates and Assumptions,” ̶ 0;Certain Trends and Uncertainties” and elsewhere in Management’s Discussion and Analysis of Financial Condition and Results of Operations.  Except as set forth under “Certain Trends and Uncertainties” and elsewhere under Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations of this Quarterly Report on Form 10-Q, we do not believe there have been any material changes to the risk factors previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2009 as supplemented by Item 1A. of our Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2010, and June 30, 2010.


 
43 
 

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

The following table summarizes information about shares of Common Stock that were purchased during the third quarter of 2010.


                 Total Number of      Maximum        
                 Shares Purchased      Number of Shares        
    Total Number             as Part of Publicly      that May Yet Be        
     of Shares      Average Price      Announced Plans      Purchased Under        
Period
  
Purchased
    
Paid per Share
    
   or Programs (1)
    
  the Plan
        
                               
July 1 through July 31
     -     $ -       -       -        
August 1 through August 31
     -     $ -       -       9,216,008  (2)        
September 1 through September 30
     -     $ -       -       -          
Total
     -               -       9,216,008          

(1)  We maintain a share repurchase program, which was authorized by the Board of Directors and announced on November 14, 2005 that provides we may repurchase shares of Common Stock for an aggregate amount not to exceed $500 million. The Repurchase Program does not require us to acquire any specific number of shares, may be terminated at any time and has no expiration date.

(2)  Calculated using the $388 million that may yet be purchased under the Repurchase Program and a price per share of $42.12, the closing price of Common Stock as reported on the New York Stock Exchange on October 27, 2010.

Item 5. Other Information

Dodd-Frank Act Disclosure of Mine Safety and Health Administration Safety Data

We are committed to providing a safe workplace for all of our employees.  Our company has in place health and safety programs that include extensive employee training, accident prevention, workplace inspection, emergency response, accident investigation, regulatory compliance and program auditing. The objectives of our health and safety programs are to eliminate workplace incidents, comply with all mining-related regulations and provide support for both regulators and the industry to improve mine safety.  We believe our company has a well-developed process of training, mentoring, monitoring, reduction of risk through safety innovation, and recognition of safety excellence.
 
 
The operation of our mines is subject to regulation by the MSHA under the Federal Mine Safety and Health Act of 1977 (the “FMSH Act”). MSHA inspects our mines on a regular basis and issues various citations and orders when it believes a violation has occurred under the FMSH Act. We present information below regarding certain mining safety and health citations which MSHA has issued with respect to our coal mining operations. In evaluating this information, consideration should be given to factors such as: (i) the number of citations and orders will vary depending on the size of the coal mine, (ii) the number of citations issued will vary from inspector to inspector and mine to mine, and (iii) citations and orders can be contested and appealed, and in that process, are often reduced in severity and amount, and are sometimes dismissed.

As required by the reporting requirements regarding coal mine safety included in §1503(a)(1) of the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”), the table below presents the following information for the three months ended September 30, 2010, except for pending legal actions, which are as of September 30, 2010, for each coal mine of which we or a subsidiary of ours is an operator:
 
(a)  
The total number of FMSH Act section 104 significant and substantial citations received, which are for alleged violations of a mining safety standard or regulation where there exists a reasonable likelihood that the hazard could result in an injury or illness of a reasonably serious nature;
 
 
 44
 
(b)  
The total number of FMSH Act section 104(b) orders received, which are for an alleged failure to totally abate the subject matter of a FMSH Act section 104(a) citation within the period specified in the citation;
 
(c)  
The total number of FMSH Act section 104(d) citations and orders received, which are for an alleged unwarrantable failure (i.e., aggravated conduct constituting more than ordinary negligence) to comply with a mining safety standard or regulation;
 
(d)  
The total number of flagrant violations (i.e., reckless or repeated failure to make reasonable efforts to eliminate a known violation of a mandatory health or safety standard that substantially and proximately caused, or reasonably could have been expected to cause, death or serious bodily injury) under §110(b)(2) of the FMSH Act received;
 
(e)  
The total number of imminent danger orders (i.e., the existence of any condition or practice in a coal or other mine which could reasonably be expected to cause death or serious physical harm before such condition or practice can be abated) issued under §107(a) of the FMSH Act;
 
(f)  
The total dollar value of proposed assessments from MSHA under the FMSH Act.  With respect to the total dollar value, the information provided is based upon the most current information available from MSHA as of October 12, 2010, as well as our estimate of assessments for violations received for which such information has not yet been made available;
 
(g)  
The total number of mining-related fatalities; and
 
(h)  
The total number of pending legal actions before the Federal Mine Safety and Health Review Commission as required by §1503(a)(3) of the Dodd-Frank Act; see Exhibit 99.1 for a complete listing of pending legal actions for each coal mine of which we or a subsidiary of ours is an operator.
 
 
Mine
( a ) #
( b ) #
( c ) #
( d ) #
( e ) #
 ( f ) $
(g) #
(h) #
#1 Prep Plant (Sidney)
 -
 -
 -
 -
 -
 $112
  
 8
Alex Energy Loadout
 -
 -
 -
 -
 -
 $112
  
 1
Allegiance Mine
 19
 -
 8
 -
 -
 $221,592
  
 20
Allen Powellton Mine
 10
 -
 -
 -
 -
 $34,120
  
 7
Alloy Powellton
 6
 -
 -
 -
 -
 $185,301
  
 -
Aracoma Alma Mine #1
 33
 1
 1
 -
 -
 $57,688
  
 5
Bent Branch Energy Co Mine No 1
 -
 -
 -
 -
 -
 $-
  
 1
Beetree Surface Mine
 3
 -
 -
 -
 -
 $2,093
  
 -
Big Creek No 2 Surface Mine
 1
 -
 -
 -
 -
 $525
  
 -
Black Castle Mining Co
 19
 1
 -
 -
 -
 $39,817
  
 7
Black King I North Portal
 10
 -
 1
 -
 -
 $25,380
  
 10
Black Knight II
 5
 -
 -
 -
 -
 $10,892
  
 16
Blue Pennant Transfer
 -
 -
 -
 -
 -
 $112
  
 1
Brushy Eagle
 6
 -
 2
 -
 -
 $18,167
  
 9
Camp Branch Mine
 -
 -
 -
 -
 -
 $-
  
 6
Castle East Portal
 -
 -
 -
 -
 -
 $112
  
 3
Castle Mine
 -
 1
 -
 -
 -
 $1,693
  
 11
Cedar Grove #1 Mine
 1
 -
 -
 -
 -
 $727
  
 -
Chess Processing
 3
 -
 -
 -
 -
 $4,609
  
 4
Chesterfield Prep Plant
 -
 -
 -
 -
 -
 $-
  
 6
Coal Creek Prep Plant
 2
 -
 2
 -
 -
 $8,310
  
 -
Cook Mine
 11
 -
 -
 -
 -
 $8,913
  
 -
Coon Cedar Grove Mine
 -
 -
 -
 -
 -
 $336
  
 8
Delbarton Preparation Plant
 -
 -
 -
 -
 -
 $-
  
 5
Derby Wilson Mine
 15
 -
 -
 -
 1
 $13,140
  
 -

 
 
 45
 
 
Mine
( a ) #
( b ) #
( c ) #
( d ) #
( e ) #
 ( f ) $
(g) #
(h) #
Diamond Energy
 22
 -
 -
 -
 -
 $48,545
  
 13
Edwight Surface Mine
 -
 -
 -
 -
 -
 $-
  
 4
Emily Creek Energy
 -
 -
 -
 -
 -
 $-
  
 1
Fraley Branch Surface Mine
 5
 -
 -
 -
 -
 $4,023
  
 6
Freeze Fork Surface Mine
 -
 -
 -
 -
 -
 $-
  
 12
Grassy Creek No 1
 8
 -
 1
 -
 -
 $32,838
  
 17
Green Valley Trucking
 -
 -
 -
 -
 -
 $1,523
  
 1
Guyandotte Energy Slope Mine #2
 -
 -
 -
 -
 -
 $-
  
 2
Halfway Branch Surface Mine
 -
 -
 -
 -
 -
 $112
  
 -
Hatfield Energy Mine
 13
 -
 -
 -
 -
 $30,902
  
 2
Hernshaw Mine
 3
 -
 -
 -
 -
 $5,507
  
 1
Highland Coal Handling Facility
 -
 -
 -
 -
 -
 $336
  
 2
Homer III Processing
 1
 -
 -
 -
 -
 $2,688
  
 2
Hominy Creek Mine
 5
 -
 -
 -
 -
 $7,594
  
 3
Horse Creek Eagle
 12
 1
 -
 -
 -
 $35,240
  
 8
Hunter Peerless Mine
 1
 -
 -
 -
 -
 $4,666
  
 2
Hurricane Branch Strip #1
 -
 -
 -
 -
 -
 $112
  
 -
Massey HWM #11
 2
 -
 -
 -
 -
 $6,619
  
 -
Jerry Fork Eagle
 -
 -
 -
 -
 -
 $2,953
  
 10
Justice #1
 21
 -
 2
 -
 -
 $123,067
  
 22
Kepler Sewell Mine #1
 -
 -
 -
 -
 -
 $112
  
 -
Laurel Coalburg Tunnel Mine
 13
 -
 2
 -
 -
 $110,276
  
 2
Laurel Creek/Spirit Mine
 -
 -
 -
 -
 -
 $540
  
 2
Liberty Processing
 -
 -
 -
 -
 -
 $-
  
 7
Lower Big Branch Impoundment
 -
 -
 -
 -
 -
 $112
  
 -
Coalgood Loadout
 1
 -
 -
 -
 -
 $1,347
  
 -
Long Fork Preparation Plant
 2
 -
 -
 -
 -
 $1,034
  
 18
Long Pole Energy Mine
 4
 -
 -
 -
 -
 $2,683
  
 1
Looney Creek Marker Mine
 3
 -
 -
 -
 -
 $7,032
  
 -
Looney Creek Taggart Mine
 19
 -
 -
 -
 -
 $29,794
  
 -
Love Branch Mine Count
 -
 -
 -
 -
 -
 $-
  
 20
Love Branch South
 27
 1
 -
 -
 -
 $42,334
  
 2
Low Splint A Mine
 15
 -
 -
 -
 -
 $30,263
  
 -
Mammoth #2 Gas
 7
 -
 -
 -
 -
 $18,602
  
 7
Mammoth Coal  Processing Pl & Riv Tipple
 -
 -
 -
 -
 -
 $2,330
  
 -
Marfork Processing
 1
 -
 -
 -
 -
 $308
  
 4
Marker Portal Mine
 -
 -
 -
 -
 -
 $120
  
 -
Marsh Fork Mine
 21
 2
 9
 -
 -
 $192,924
  
 9
Meade Branch Surface
 1
 -
 -
 -
 -
 $176
  
 1
Mine #1 (Cave Spur)
 5
 -
 -
 -
 -
 $10,832
  
 -
Mine #1 (Clean Energy)
 18
 1
 5
 -
 -
 $67,798
  
 30
Mine #1 (Freedom Energy)
 59
 -
 18
 -
 -
 $256,074
  
 62
Mine #1 (Rockhouse Energy)
 17
 -
 -
 -
 -
 $68,035
  
 31
Mine #1 (Solid Energy)
 7
 -
 -
 -
 -
 $14,627
  
 15
Mine No 1 (Bluff Spur)
 4
 -
 -
 -
 -
 $6,462
  
 -
Mine No 1 (Stillhouse Mining)
 4
 -
 -
 -
 -
 $12,842
  
 1
Mine No 2 (Big Laurel Mining)
 14
 -
 -
 -
 -
 $26,323
  
 15
Mine No 2 (Stillhouse Mining)
 7
 -
 -
 -
 -
 $10,486
  
 -
Mine No 4 (North Fork)
 16
 -
 -
 -
 -
 $27,244
  
 7
Mine No 5 (Guest Mountain)
 5
 -
 -
 -
 -
 $13,335
  
 2

 
 46
 
Mine
( a ) #
( b ) #
( c ) #
( d ) #
( e ) #
 ( f ) $
(g) #
(h) #
Mine No 5 (North Fork)
 9
 -
 -
 -
 -
 $22,021
  
 -
Mine No. 1 (Cloverlick Coal)
 7
 -
 -
 -
 -
 $8,796
  
 -
Mine No. 1 (Osaka Mining)
 31
 1
 1
 -
 -
 $78,996
  
 2
Mine No. 1 (Panther Mining)
 32
 -
 -
 -
 -
 $85,464
  
 1
Mine No. 3 (Cloverlick Coal)
 5
 -
 -
 -
 -
 $7,140
  
 -
Mine No. 3 (Mill Branch Coal)
 3
 -
 -
 -
 -
 $7,413
  
 -
Mine No. 4 (Dorchester)
 20
 -
 -
 -
 -
 $39,585
  
 4
Moore Processing
 -
 -
 -
 -
 -
 $2,385
  
 -
MTR Surface Mine
 -
 -
 -
 -
 -
 $-
  
 3
MTR Wolf Creek Mine
 -
 -
 -
 -
 -
 $112
  
 4
New Ridge Mining Company
 -
 -
 -
 -
 -
 $112
  
 4
No 1 (M3 Energy)
 4
 1
 -
 -
 -
 $6,144
  
 20
No 1 Preparation Plant (Green Valley)
 3
 -
 -
 -
 -
 $2,243
  
 -
No 1 Surface (Alex Energy)
 -
 -
 -
 -
 -
 $-
  
 8
No 130 Mine
 -
 -
 -
 -
 -
 $2,848
  
 7
No. 1 (Process Energy)
 16
 -
 -
 -
 -
 $20,933
  
 18
North Surface Mine
 -
 -
 -
 -
 -
 $-
  
 4
Parker Peerless Mine
 11
 -
 4
 -
 1
 $52,380
  
 11
Phillips Rider No. 1 Mine
 2
 -
 -
 -
 -
 $626
  
 -
Plant No 1 (Pigeon Creek)
 1
 -
 -
 -
 -
 $1,413
  
 -
Pocahontas Mine
 36
 -
 3
 -
 -
 $35,138
 1
 1
Power Mountain Processing
 3
 -
 1
 -
 -
 $7,279
  
 2
Preparation Plant (Goals)
 -
 -
 -
 -
 -
 $-
  
 1
Preparation Plant (Martin County)
 31
 4
 1
 -
 1
 $31,993
  
 2
Preparation Plant (Stirrat)
 1
 -
 -
 -
 -
 $2,341
  
 2
Randolph Mine
 34
 1
 6
 -
 -
 $176,966
  
 10
Red Cedar Surface
 -
 -
 -
 -
 -
 $-
  
 4
Republic Energy
 5
 -
 -
 -
 -
 $7,513
  
 3
Right Fork Splint
 -
 -
 -
 -
 -
 $348
  
 1
River Fork Powellton #1
 -
 -
 -
 -
 -
 $-
  
 1
Road Fork #51 Mine
 24
 -
 2
 -
 1
 $104,574
  
 14
Roundbottom Powellton Deep Mine
 22
 -
 2
 -
 -
 $91,645
  
 11
Round Bottom Surface Mine
 1
 -
 -
 -
 -
 $532
  
 1
Ruby Energy
 31
 -
 8
 -
 -
 $292,287
  
 21
Rum Creek Preparation Plant
 6
 -
 2
 -
 -
 $20,520
  
 7
Seng Creek Powellton
 42
 -
 10
 -
 1
 $170,459
  
 3
Shadrick 5 Block
 14
 -
 1
 -
 -
 $174,980
  
 2
Sidney Coal Company, Inc.
 -
 -
 -
 -
 -
 $-
  
 1
Sidney Trucking
 -
 -
 -
 -
 -
 $-
  
 1
Slabcamp
 14
 -
 1
 -
 -
 $87,896
  
 2
Slip Ridge Cedar Grove Mine
 24
 -
 2
 -
 -
 $84,817
  
 14
Stockton Mine
 2
 -
 -
 -
 -
 $2,626
  
 1
Superiour Surface Mine
 -
 -
 -
 -
 -
 $-
  
 7
Talon Loadout
 1
 1
 -
 -
 -
 $750
  
 -
Taylor Fork Energy
 25
 1
 -
 -
 -
 $51,188
  
 21
Tiller No 1
 26
 -
 3
 -
 -
 $46,839
  
 32
Tower Mountain
 -
 -
 -
 -
 -
 $-
  
 3
Trace Transport
 -
 -
 -
 -
 -
 $13,239
  
 -
Transport Mine
 1
 -
 -
 -
 -
 $585
  
 -
Triumph Mine
 33
 7
 4
 -
 -
 $85,713
  
 9


 
47 
 

Mine
( a ) #
( b ) #
( c ) #
( d ) #
( e ) #
 ( f ) $
(g) #
(h) #
Tunnel Mine
 1
 -
 -
 -
 -
 $763
  
 -
Twilight Mtr Surface Mine
 7
 -
 -
 -
 -
 $9,435
  
 -
Upper Big Branch Mine Raw Coal Facility
 -
 -
 -
 -
 -
 $-
  
 1
Upper Big Branch Mine-South
 161
 12
 17
 -
 2
 $590,327
  
 52
Voyager #7
 12
 -
 -
 -
 -
 $116,802
  
 14
West Cazy Surface Mine
 -
 -
 -
 -
 1
 $-
  
 2
White Buck No. 2
 -
 -
 -
 -
 -
 $112
  
 2
White Cabin #7
 9
 -
 -
 -
 -
 $10,712
  
 6
White Queen
 -
 -
 -
 -
 -
 $100
  
 6
Winifrede #1 Mine Count
 -
 -
 -
 -
 -
 $-
  
 2
Zigmond Processing
 2
 -
 -
 -
 -
 $1,615
  
 -
 

In addition, as required by the reporting requirements regarding coal mine safety included in §1503(a)(2) of the Dodd-Frank Act, the following is a list for the three months ended September 30, 2010, of each coal mine of which we or a subsidiary of ours is an operator, that has received written notice from MSHA of:

(a)  
a pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards under §104(e) of the FMSH Act:

None; or

(b)  
the potential to have such a pattern:

None

 
48 
 

Item 6. Exhibits
3.1
Amended and Restated Certificate of Incorporation effective October 6, 2010 [filed as Exhibit 3.1 to the Company’s Form 8-K filed on October 6, 2010 and incorporated by reference].
3.2
Amended and Restated Bylaws (as amended and restated as of October 6, 2010) of Massey Energy Company [filed herewith].
31.1
Certification of Chief Executive Officer, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 [filed herewith].
31.2
Certification of Chief Financial Officer, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 [filed herewith].
32.1
Certification of Chief Executive Officer pursuant to 18 U.S.C., Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 [furnished herewith].
32.2
Certification of Chief Financial Officer pursuant to 18 U.S.C., Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 [furnished herewith].
99.1
Pending legal actions before the Federal Mine Safety and Health Review Commission for each coal mine of which Massey Energy Company or a subsidiary of Massey Energy Company is an operator as required by §1503(a)(3) of the Dodd-Frank Wall Street Reform and Consumer Protection Act.
101
Interactive Data File (Quarterly Report on Form 10-Q, for the quarterly period ended September 30, 2010, furnished in XBRL (eXtensible Business Reporting Language)).
 
Attached as Exhibit 101 to this report are the following documents formatted in XBRL:  (i) the Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2010 and 2009, (ii) the Condensed Consolidated Balance Sheets at September 30, 2010 and December 31, 2009, (iii) the Condensed Consolidated Statements of Cash Flows for the three and nine months ended September 30, 2010 and 2009 and (iv) the Notes to Condensed Consolidated Financial Statements, tagged as blocks of text. Users of this data are advised pursuant to Rule 406T of Regulation S-T that this interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of sections 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of section 18 of the Securities Exchan ge Act of 1934, and otherwise is not subject to liability under these sections.


 
49 
 

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.
 
 
   MASSEY ENERGY COMPANY  
   (Registrant)  
     
     
 Date:  November 8, 2010   /s/ Eric. B. Tolbert  
  Eric B. Tolbert,  
  Vice President and Chief Financial Officer  
     
     
 Date:  November 8, 2010  /s/ David W. Owings  
  David W. Owings,  
  Controller  
 
 
 
                                                                              
 
 
50


 
 

EX-31.1 2 exhibit311.htm SECTION 302 CEO CERTIFICATION exhibit311.htm
 
EXHIBIT 31.1

Section 302 Certification

I, Don L. Blankenship, certify that:

1.  
I have reviewed this quarterly report on Form 10-Q for the quarter ended September 30, 2010 of Massey Energy Company;

2.  
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.  
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)  
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)  
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  
evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report based on such evaluation; and

(d)  
disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.  
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)  
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)  
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 
 

 
 Date:  November 8, 2010 /s/ Don L. Blankenship
  Don L. Blankenship
  Chairman and Chief Executive Officer
EX-31.2 3 exhibit312.htm SECTION 302 CFO CERTIFICATION exhibit312.htm
 
EXHIBIT 31.2

Section 302 Certification

I, Eric B. Tolbert, certify that:

1.  
I have reviewed this quarterly report on Form 10-Q for the quarter ended September 30, 2010 of Massey Energy Company;

2.  
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.  
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)  
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)  
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  
evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report based on such evaluation; and

(d)  
disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.  
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)  
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)  
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
 
 Date:  November 8, 2010 /s/ Eric B. Tolbert
  Eric B. Tolbert
  Vice President and Chief Financial Officer
 
 
 

 EX-32.1 4 exhibit321.htm SECTION 906 CEO CERTIFICATION exhibit321.htm
 
EXHIBIT 32.1
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report on Form 10-Q of Massey Energy Company (the “Company”) for the quarter ending September 30, 2010 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Don L. Blankenship, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)           the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2)           the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ Don L. Blankenship
  
Don L. Blankenship
Chairman and Chief Executive Officer

November 8, 2010
 
 

 EX-32.2 5 exhibit322.htm SECTION 906 CFO CERTIFICATION exhibit322.htm
 
EXHIBIT 32.2

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report on Form 10-Q of Massey Energy Company (the “Company”) for the quarter ending September 30, 2010 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Eric B. Tolbert, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)           the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2)           the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ Eric B. Tolbert  
Eric B. Tolbert
Vice President and Chief Financial Officer

November 8, 2010

 EX-3.2 6 exhibit32.htm RESTATED BYLAWS (OCT 6, 2010) exhibit32.htm

 
EXHIBIT 3.2

RESTATED BYLAWS
 
(as amended as of October 6, 2010)
 
OF
 
MASSEY ENERGY COMPANY
 
(a Delaware corporation)
 
ARTICLE I
 
OFFICES
 
Section 1.01   Registered Office.   The registered office of MASSEY ENERGY COMPANY (hereinafter called the “Corporation”) in the State of Delaware shall be at 160 Greentree Drive, Suite 101, City of Dover, County of Kent, and the name of the registered agent at that address shall be National Registered Agents, Inc.
 
Section 1.02   Principal Office.   The principal office for the transaction of the business of the Corporation shall be at Four North Fourth Street, Richmond, Virginia 23219.   The Board of Directors (hereinafter called the “Board”) is hereby granted full power and authority to change said principal office from one location to another.
 
Section 1.03   Other Offices.   The Corporation may also have an office or offices at such other place or places, either within or without the State of Delaware, as the Board may from time to time determine or as the business of the Corporation may require.
 
ARTICLE II
 
MEETINGS OF STOCKHOLDERS
 
Section 2.01   Annual Meetings.   Annual meetings of the stockholders of the Corporation (the “Stockholders”) for the purpose of electing directors and for the transaction of such other proper business as may come before such meetings may be held at such time, date and place as the Board shall determine by resolution. 
 
Section 2.02   Special Meetings. 
 
(a) General.  Special meetings of the Stockholders for any purpose or purposes may be called at any time by the Board or by a committee of the Board which has been duly designated by the Board and whose powers and authority, as provided in a resolution of the Board or in these Amended and Restated Bylaws (the “Bylaws”), include the power to call such meeting, but such special meetings may not be called by any other person or persons; provided, however, that if and to the extent that any special meetings of the Stockholders may be called by any other person or persons specified in any provisions of the Certificate of Incorporation or any amendment thereto or any certificate filed under Section 151(g) of the Delaware General Corporation Law (or its successor statute as in effect from time to time hereafter), then such special meeting may also be called by the person or persons, in the manner, at the times and for the purposes so specified.
 
(b) Stockholder Requested Special Meeting.  (1) A special meeting of the Stockholders shall be called by the Board upon written request to the Secretary of the Corporation (the “Secretary”) (a “Special Meeting Request”) of one or more Stockholders of record at the time of delivery of the written request representing in the aggregate not less than twenty-five percent (25%) of the total number of shares of stock entitled to vote on the matter or matters to be brought before the proposed special meeting of the Stockholders.  A Special Meeting Request shall be signed by each Stockholder, or a duly authorized agent of such Stockhol der, requesting the special meeting and shall set forth: (i) a brief description of each matter of business desired to be brought before the special meeting and the reasons for conducting such business at the special meeting, (ii) the name and address, as they appear on the Corporation’s books, of each Stockholder requesting the special meeting, (iii) the class and number of shares of the Corporation which are owned by each Stockholder requesting the special meeting, including shares beneficially owned and shares held of record, (iv) any material interest of each Stockholder in the business desired to be brought before the special meeting, and (v) any other information, documents and representations that is required under Section 2.04(a)(ii) herein.  The Board shall determine whether all such requirements have been satisfied and such determination shall be binding on the Corporation and the Stockholders.
 
       (2)  A special meeting requested by the Stockholders shall be held at such date, time and place within or without the state of Delaware as may be fixed by the Board; provided, however, the Board may (in lieu of calling the special meeting requested in such Special Meeting Request) present an identical or substantially similar item (a “Similar Item,” and the election of directors shall be deemed a “Similar Item” with respect to all items of business involving the election or removal of directors) for Stockholder approval at any other meeting of the Stockholders that is held not less than one hundred twenty (120) calen dar days after the Secretary receives such Special Meeting Request.  A Stockholder may revoke a Special Meeting Request at any time by written revocation delivered to the Secretary; provided, however, the Board shall have the discretion to determine whether or not to proceed with the special meeting.  If, following a revocation of a Special Meeting Request, there are un-revoked requests from the Stockholders holding in the aggregate less than the requisite number of shares entitling the Stockholders to request the calling of a special meeting, the Board, in its discretion, may cancel the special meeting.
 
(3)  A Special Meeting Request shall not be valid if (i) the Special Meeting Request relates to an item of business that is not a proper subject for Stockholder action under applicable law, (ii) a Similar Item was presented at any meeting of the Stockholders held within one hundred twenty (120) calendar days prior to receipt by the Corporation of such Special Meeting Request, (iii) a Similar Item is included in the Corporation’s notice as an item of business to be brought before a Stockholder meeting that has been called but not yet held or (iv) the Special Meeting Request is received by the Corporation during the period commencing ninety (90) calendar days prior to the first anniversary of the preceding year’s annual meeting and ending on the date of that year’s annual meeting of the Stockholders.
 
(4)  Business transacted at a special meeting requested by the Stockholders shall be limited to the purposes stated in the request for the special meeting; provided, however, that nothing herein shall prohibit the Board from submitting additional matters to the Stockholders at any such special meeting.
 
(5)  If none of the Stockholders who submitted the Special Meeting Request for a special meeting of the Stockholders appears or sends a representative to present the proposal(s) or business submitted by the Stockholders for consideration at the special meeting, the Corporation need not present such proposal(s) or business for a vote at such meeting.
 
Section 2.03   Place of Meetings.   All meetings of the Stockholders shall be held at such places, within or without the State of Delaware, as may from time to time be designated by the person or persons calling the respective meeting and specified in the respective notices or waivers of notice thereof.
 
Section 2.04   Notice of Stockholder Business.
 
(a)   Annual Meetings of Stockholders. (i) Nominations of persons for election to the Board and the proposal of business to be considered by the Stockholders may be made at an annual meeting of the Stockholders (A) pursuant to the Corporation’s notice of meeting delivered pursuant to Section 2.05, (B) by or at the direction of the Chairman of the Board (the “Chairman”) or (C) by any Stockholder who is entitled to vote at the meeting, who complied with the notice procedures set forth in Section 2.04(a)(ii) and Section 2.04(a)(iii), who was a Stockholder of record at the time such notice is delivered to the Secretary an d who, together with each Covered Person (as defined in Section 2.04(a)(ii)(E)(1)), if any, has complied with the notice requirements of Section 2.10 from and including the later of (1) the date falling 20 days after the date of the Public Announcement (as defined in Section 2.04(c)(ii)) of the adoption of these Bylaws and (2) the date of the immediately preceding annual meeting of the Stockholders (such later date, the “Notice Compliance Commencement Date”) to and including the date of delivery of such notice.
 
(ii)  For nominations or other business to be properly brought before an annual meeting by a Stockholder pursuant to Section 2.04(a)(i)(C), the Stockholder must have given timely notice thereof in writing to the Secretary and, in the case of business other than nominations, such other business must otherwise be a proper matter for Stockholder action.  To be timely, a Stockholder’s notice shall be delivered to the Secretary at the principal executive offices of the Corporation not less than 90 days nor more than 120 days prior to the first anniversary of the preceding year’s annual meeting; provided, however, that in the event that the date of the annual meeting is advanced by more than 30 days, or delayed by more than 90 days, from such anniversary date, notice by the Stockholder to be timely must be so delivered not earlier than the 120th day prior to such annual meeting and not later than the close of business on the later of the 90th day prior to such annual meeting or the 10th day following the day on which the Public Announcement of the date of such meeting is first made by the Corporation.  In no event shall the Public Announcement of an adjournment or postponement of an annual meeting commence a new time period for the giving of a Stockholder’s notice as described in this Section 2.04(a).
 
Such Stockholder’s notice shall set forth and include the following information and/or documents, as applicable, (A) the name and address of the Stockholder giving the notice, as they appear on the Corporation’s books, and of the Beneficial Owner (as defined in Section 2.10(b)), if any, on whose behalf such nomination or proposal is made, (B) representations that, as of the date of delivery of such notice, (1) such Stockholder is a holder of record of stock of the Corporation and is entitled to vote at such meeting and intends to appear in person or by proxy at such meeting to propose such nomination or business and (2) such Stockholder
 
and each Covered Person, if any, has complied with the notice requirements of Section 2.10 from and including the Notice Compliance Commencement Date to and including the date of delivery of such notice, (C) as to each person whom the Stockholder proposes to nominate for election or reelection as a director (a “Stockholder Nominee”), (1) all information relating to such Stockholder Nominee that is required to be disclosed in solicitations of proxies for election of directors in an election contest, or is otherwise required, in each case pursuant to Regulation 14A under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and Rule 14a-11 thereunder (or any successor provisions thereto), including such Stockholder Nominee’s written consent to being named in the proxy statement as a nominee and to serving as a director if elected and (2) such other information, com pleted questionnaire and the Agreement (as defined in Section 3.02), duly executed by such Stockholder Nominee, in each case, as required under Section 3.02; (D) as to any other business that the Stockholder proposes to bring before the meeting, (1) a brief description of the business proposed to be brought before the meeting, (2) the text of the proposal (including the text of any resolutions proposed for consideration and, in the event that such business includes a proposal to amend these Bylaws, the text of the proposed amendment) and (3) the reasons for conducting such business at the meeting; and (E) in all cases, (1) the name of each individual, firm, corporation, limited liability company, partnership, trust or other entity (including any successor thereto, a “Person”) with whom any Stockholder, Beneficial Owner, Stockholder Nominee, and their respective Affiliates and Associates (as defined under Regulation 12B under the Exchange Act or any successor pro vision thereto) (each of the foregoing, a “Stockholder Group Member”) and each other Person with whom such Stockholder Group Member is acting in concert with respect to the Corporation (each Person described in this clause (1), including each Stockholder Group Member, a “Covered Person”) has any agreement, arrangement or understanding (whether written or oral) for the purpose of acquiring, holding, voting (except pursuant to a revocable proxy given to such Person in response to a public proxy solicitation made generally by such Person to all holders of voting stock of the Corporation (“Voting Stock”)) or disposing of any Voting Stock or to cooperate in obtaining, changing or influencing the control of the Corporation (except independent financial, legal and other advisors acting in the ordinary course of their respective businesses), and a description of each such agreement, arrangement or understanding (whether written or oral), (2) a list of the class and numbe r of shares of Voting Stock that are Beneficially Owned (as defined in Section 2.10(b)) or owned of record by each Covered Person, together with documentary evidence of such record or Beneficial Ownership (as defined in Section 2.10(b)), (3) a list of (A) all of the derivative securities (as defined under Rule 16a-1 under the Exchange Act) and other derivatives or similar agreements or arrangements with an exercise or conversion privilege or a periodic or settlement payment or payments or mechanism at a price or in an amount or amounts related to any security of the Corporation or with a value derived or calculated in whole or in part from the value of any security of the Corporation, in each case, directly or indirectly owned of record or Beneficially Owned by any Covered Person and (B) each other direct or indirect opportunity of any Covered Person to profit or share in any profit derived from any increase or decrease in the value of any security of the Corporation, in each case, r egardless of whether (x) such interest conveys any voting rights in such security to such Covered Person, (y) such interest is required to be, or is capable of being, settled through delivery of such security or (z) such Person may have entered into other transactions that hedge the economic effect of such interest (any such interest described in this clause (3) being a “Derivative Interest”), (4) a description of each agreement, arrangement or understanding (whether written or oral) with the effect or intent of increasing or decreasing the voting power of, or that contemplates any Person voting together with, any Covered Person with respect to any Voting Stock, Stockholder Nominee or other proposal (“Voting Arrangements”), (5) details of all other material interests of each Covered Person in such nomination or proposal or capital stock of the Corporation (including any rights to dividends or performance related fees based on any increase or decrease in t he value of such capital stock or Derivative Interests) (collectively, “Other Interests”), (6) a description of all economic terms of all such Derivative Interests, Voting Arrangements and Other Interests and copies of all agreements and other documents (including but not limited to master agreements, confirmations and all ancillary documents and the names and details of the counterparties to, and brokers involved in, all such transactions) relating to each such Derivative Interest, Voting Arrangement and Other Interests, (7) a list of all transactions by each Covered Person involving any Voting Stock or any Derivative Interests, Voting Arrangements or Other Interests within 6 months prior to the date of the notice, and (8) a representation whether any Covered Person intends or is part of a group which intends (a) to deliver a proxy statement and/or form of proxy to holders of at least the percentage of the Corporation’s outstanding capital stock required to approve or a dopt the proposal or elect any Stockholder Nominee and/or (b) otherwise to solicit or participate in the solicitation of proxies from the Stockholders in support of such nomination or proposal and (9) all other information that, as of the date of delivery of such notice, would be required to be provided to the Corporation under Section 2.10 by any Covered Person, regardless of whether such Covered Person has previously provided such information to the Corporation.  A notice delivered by or on behalf of any Stockholder under this Section 2.04(a) shall be deemed to be not in compliance with this Section 2.04(a) and not effective if (x) such notice does not include all of the information and documents required under this Section 2.04(a), (y) such Stockholder, together with each Covered Person, if any, fails to comply with the requirements of Section 2.10 from and including the date of delivery of such notice to and including the date of the meeting to which such notice relates or (z) or (y) after delivery of such notice, any information or document required to be included in such notice changes or is amended, modified or supplemented, as applicable, prior to the date of the relevant meeting and such information and/or document is not delivered to the Corporation by way of a further written notice as promptly as practicable following the event causing such change in information or amendment, modification or supplement, as applicable, and in any case where such event occurs within 45 days of the date of the relevant meeting, within five business days after such event; provided, however, that the Board shall have the authority to waive any such non-compliance if the Board determines that such action is appropriate in the exercise of its fiduciary duties.  The foregoing notice requirements of this Section 2.04(a) shall be deemed satisfied by a Stockholder if the Stockholder has notified the Corporation of such Stockholder’s intention to present a proposal at an annual meeting in compliance with applicable rules and regulations promulgated under the Exchange Act and such Stockholder’s proposal has been included in a proxy statement that has been prepared by the
 
Corporation to solicit proxies for such annual meeting.  The Corporation may require any Stockholder Nominee to furnish such other information as it may reasonably require to determine the eligibility of such Stockholder Nominee to serve as a director.
 
(iii)  Notwithstanding anything in the second sentence of Section 2.04(a)(ii) to the contrary and subject to Section 3.03, in the event that the number of directors to be elected to the Board is increased effective at the annual meeting and there is no Public Announcement naming all of the nominees for director or specifying the size of the increased Board made by the Corporation at least 100 days prior to the first anniversary of the preceding year’s annual meeting, a Stockholder’s notice required by this Section 2.04(a) shall also be considered timely, but only with respect to nominees for any new positions created by such increase, if it shall be delivered to the Secretary at the principal executive offices of the Corporation not later than the close of business on the 10th day following the day on whic h such Public Announcement is first made by the Corporation and such notice otherwise complies with the requirements of this Section 2.04(a).
 
(b)  Special Meetings of Stockholders.  Only such business shall be conducted at a special meeting of the Stockholders as shall have been brought before the meeting pursuant to the Corporation’s notice of meeting pursuant to Section 2.05.  Nominations of persons for election to the Board may be made at a special meeting of the Stockholders at which directors are to be elected pursuant to the Corporation’s notice of meeting (A) by or at the direction of the Board (or the Stockholders pursuant to Section 2.02(b) hereof) or (B) provided that the Board (or the Stockholders pursuant to Section 2.02(b) hereof) has determined that directors shall be elected at such meeting, by any Stockholder of the Corporation who is entitled to vote at the meeting, who complies with the notice procedures set forth in this Section 2.04(b), who is a Stockholder of record at the time such notice is delivered to the Secretary and who, together with each Covered Person, if any, has complied with the requirements of Section 2.10 from and including the Notice Compliance Commencement Date to and including the date of delivery of such notice.  In the event the Corporation calls a special meeting of the Stockholders for the purpose of electing one or more directors to the Board, any such Stockholder may nominate such number of persons for election to such position(s) as are specified in the Corporation’s notice of meeting, if the Stockholder’s notice, containing all of the information, documents and representations required under Section 2.04(a)(ii), shall be delivered to the Secretary at the principal executive offices of the Corporation not earlier than the 120th day prior to such special meeting and not later than the close of business on the later of the 90th day prior to such special meeting or the 10th day following the day on which Public Announcement of the date of the special meeting and of the nominees proposed by the Board to be elected at such meeting is first made by the Corporation.  A notice delivered by or on behalf of any Stockholder under this Section 2.04(b) shall be deemed to be not in compliance with this Section 2.04(b) and not effective if (x) such notice does not include all of the information and documents required under this Section 2.04(b), (y) such Stockholder, together with each Covered Person, if any, fails to comply with the requirements of Section 2.10 from and including the date of delivery of such notice to and including the date of the meeting to which such notice relates or (z) or (y) after delivery of such notice, any information or document required to be included in such notice changes or is amended, modified or supplemented, as ap plicable, prior to the date of the relevant meeting and such information and/or document is not delivered to the Corporation by way of a further written notice as promptly as practicable following the event causing such change in information or amendment, modification or supplement, as applicable, and in any case where such event occurs within 45 days of the date of the relevant meeting, within five business days after such event; provided, however, that the Board shall have the authority to waive any such non-compliance if the Board determines that such action is appropriate in the exercise of its fiduciary duties.  In no event shall the Public Announcement of an adjournment or postponement of a special meeting commence a new time period for the giving of a Stockholder’s notice as described above.
 
(c)  General. (i) Only persons who are nominated in accordance with the procedures and other requirements set forth in Section 2.04(a) or 2.04(b) shall be eligible to be elected as directors at a meeting of the Stockholders and only such business shall be conducted at a meeting of the Stockholders as shall have been brought before the meeting in accordance with the procedures set forth in this Section 2.04.  The Board may adopt by resolution such rules and regulations for the conduct of meetings of the Stockholders as it shall deem appropriate.  Except to the extent inconsistent with such rules and regulations as adopted by the Board, the Chairman shall have the right and authority to convene and adjourn the meeting, to prescribe such rules, regulations and procedures and to do all such acts as, in the judgment of the Chairman, are appropriate for the proper conduct of the meeting.  Such rules, regulations or procedures, whether adopted by the Board or prescribed by the Chairman, may include the following: (i) the establishment of an agenda or order of business for the meeting; (ii) rules and procedures for maintaining order at the meeting and the safety of those present; (iii) limitations on attendance at or participation in the meeting to the Stockholders of record of the Corporation, their duly authorized and constituted proxies or such other persons as the Board or the Chairman shall determine; (iv) restrictions on entry to the meeting after the time fixed for the commencement thereof; and (v) limitations on the time allotted to questions or comments by participants.  Except as otherwise provided by applicable law, the Certificate of Incorporation or these Bylaws, the Board or the Cha irman shall, if the facts warrant, determine and declare to the meeting that a matter or business was not properly brought before the meeting (including, but not limited to, whether a nomination or any business proposed to be brought before the meeting was made in accordance with the procedures and other requirements set forth in these Bylaws (including Sections 2.04 and 2.10)) and if the Board or the Chairman should so determine, shall so declare to the meeting, and any such matter or business not properly brought before the meeting shall not be transacted or considered.  Notwithstanding the foregoing provisions of this Section 2.04, unless otherwise required by applicable law, if the Stockholder (or a qualified representative of the Stockholder) does not appear at the annual or special meeting of the Stockholders to present a nomination or proposed business previously put forward by or on behalf of such
 
Stockholder or, immediately prior to the commencement of such meeting, such Stockholder does not provide a written certification to the Corporation on and as of the date of the applicable meeting that such Stockholder and each Covered Person, if any, is then in compliance with Section 2.04 and Section 2.10, then such nomination shall be disregarded and such proposed business shall not be transacted, notwithstanding that proxies in respect of such vote may have been received by the Corporation.  For purposes of this Section 2.04, to be considered a qualified representative of the Stockholder, a person must be a duly authorized officer, manager or partner of such Stockholder or must be authorized by a writing executed by such Stockholder and each Covered Person, if any, or an electronic transmission delivered by such Stockholder and each Covered Person, if any, to act for such Stockholder and eac h Covered Person, if any, as proxy at the meeting of the Stockholders and to provide such certification on behalf of the Stockholder and each Person required pursuant to this Section 2.04(c) and such Person must produce such writing or electronic transmission, or a reliable reproduction of the writing or electronic transmission, at the meeting of the Stockholders.
 
(ii)  For purposes of these Bylaws, “Public Announcement” shall mean disclosure in a press release reported by the Dow Jones News Service, Associated Press or comparable national news service or in a document publicly filed by the Corporation with the Securities and Exchange Commission pursuant to Section 13, 14 or 15(d) of the Exchange Act or any document delivered to all Stockholders.
 
(iii)  Notwithstanding the foregoing provisions of these Bylaws, a Stockholder shall also comply with all applicable requirements of the Exchange Act and the rules and regulations promulgated thereunder with respect to the matters set forth in this Section 2.04 and Section 2.10; provided, however, that any references in these Bylaws to the Exchange Act or the rules or regulations promulgated thereunder are not intended to and shall not limit any requirements applicable to nominations or proposals as to any other business to be considered pursuant to these Bylaws (including Sections 2.04(a)(i)(C) and (b) hereof), and compliance with Secti ons 2.04(a)(i)(C) and (b) of these Bylaws shall be the exclusive means for a Stockholder to make nominations or submit other business (other than, as provided in the penultimate sentence of (a)(ii), matters brought properly under and in compliance with Rule 14a-8 of the Exchange Act, as may be amended from time to time).  Nothing in these Bylaws shall be deemed to affect any rights of (a) the Stockholders to request inclusion of nominations or proposals in the Corporation’s proxy statement pursuant to Rule 14a-8 under the Exchange Act or (b) holders of any series of preferred stock to elect directors pursuant to any applicable provisions of the Certificate of Incorporation.
 
Section 2.05   Notice of Meetings.   Except as otherwise required by law, notice of each meeting of the Stockholders, whether annual or special, shall be given not less than 10 nor more than 60 days before the date of the meeting to each Stockholder of record entitled to vote at such meeting by delivering a typewritten or printed notice thereof to him or her personally, or by depositing such notice in the United States mail, in a postage prepaid envelope, directed to him or her at his or her post office address furnished by him or her to the Secretary for such purpose or, if he or she shall not have furnished to the Secretary his or her ad dress for such purposes, then at his or her post office address last known to the Secretary, or by transmitting a notice thereof to him or her at such address by telegraph, cable or wireless.   Except as otherwise expressly required by law, no publication of any notice of a meeting of the Stockholders shall be required.   Every notice of a meeting of the Stockholders shall state the place, date and hour of the meeting, and, in the case of a special meeting, shall also state the purpose or purposes for which the meeting is called.   Notice of any meeting of the Stockholders shall not be required to be given to any Stockholder who shall have waived such notice and such notice shall be deemed waived by any Stockholder who shall attend such meeting in person or by proxy, except a Stockholder who shall attend such meeting for the express purpose of objecting, at the beginning of the meeting, to the transaction of any business because the meeting is not lawfully called or convened.   Except as otherwise expressly required by law, notice of any adjourned meeting of the Stockholders need not be given if the time and place thereof are announced at the meeting at which the adjournment is taken.
 
Section 2.06   Quorum.   Except in the case of any meeting for the election of directors summarily ordered as provided by law, the holders of record of a majority in voting interest of the shares of stock of the Corporation entitled to be voted thereat, present in person or by proxy, shall constitute a quorum for the transaction of business at any meeting of the Stockholders of the Corporation or any adjournment thereof.   In the absence of a quorum at any meeting or any adjournment thereof, a majority in voting interest of the Stockholders present in person or by proxy and entitled to vote thereat or, in the absence therefrom of all the Stockholders, any officer entitled to preside at, or to act as secretary of, such meeting may adjourn such meeting from time to time.   At any such adjourned meeting at which a quorum is present any business may be transacted which might have been transacted at the meeting as originally called. 
 
Section 2.07   Voting. 
 
(a)  Each Stockholder shall, at each meeting of the Stockholders, be entitled to vote in person or by proxy each share or fractional share of the stock of the Corporation having voting rights on the matter in question and which shall have been held by him or her and registered in his or her name on the books of the Corporation:
 
(i)  on the date fixed pursuant to Section 6.05 of the Bylaws as the record date for the determination of the Stockholders entitled to notice of and to vote at such meeting, or
 
        (ii)  if no such record date shall have been so fixed, then (a) at the close of business on the day next preceding the day on which notice of the meeting shall be given or (b) if notice of the meeting shall be waived, at the close of business on the day next preceding the day on which meeting shall be held.
 
(b)           Shares of its own stock belonging to the Corporation or to another corporation, if a majority of the shares entitled to vote in the election of directors in such other corporation is held, directly or indirectly, by the Corporation, shall neither be entitled to vote nor be counted for quorum purposes. Persons holding stock of the Corporation in a fiduciary capacity shall be entitled to vote such stock. Persons whose stock is pledged shall be entitled to vote, unless in the transfer by the pledgor on the books of the Corporation he or she shall have expressly empowered the pledgee to vote thereon, in which case only the pledgee, or his or her proxy, may represent such stock and vote thereon.   Stock having voting power standing of record in the names of two or more persons, whether fiduciaries, members of a partnership, joint tenants, tenants in common, tenants by the entirety or otherwise, or with respect to which two or more persons have the same fiduciary relationship, shall be voted in accordance with the provisions of the General Corporation Law of the State of Delaware.
 
(c)           Any such voting rights may be exercised by the Stockholder entitled thereto in person or by his or her proxy appointed by an instrument in writing, subscribed by such Stockholder or by his or her attorney thereunto authorized and delivered to the secretary of the meeting; provided, however, that no proxy shall be voted or acted upon after three years from its date unless said proxy shall provide for a longer period.   The attendance at any meeting of a Stockholder who may theretofore have given a proxy shall not have the effect of revoking the same unless he or she shall in writing so notify the secretary of the meeting prior to the voting of the proxy.   At any meeting of the Stockholders all matters, except as otherwise provided in the Certificate of Incorporation, in the Bylaws or by law, shall be decided by the vote of a majority in voting interest of the Stockholders present in person or by proxy and entitled to vote thereat and thereon, a quorum being present.  The vote at any meeting of the Stockholders on any question need not be by ballot, unless so directed by the chairman of the meeting.   On a vote by ballot each ballot shall be signed by the Stockholder voting, or by his or her proxy, if there be such proxy, and it shall state the number of shares voted.
 
Section 2.08   List of Stockholders.   The Secretary shall prepare and make, at least 10 days before every meeting of the Stockholders, a complete list of the Stockholders entitled to vote at the meeting, arranged in alphabetical order, and showing the address of each Stockholder and the number of shares registered in the name of each Stockholder.  Such list shall be open to the examination of any Stockholder, for any purpose germane to the meeting, during ordinary business hours, for a period of at least 10 days prior to the meeting, either at a place within the city where the meeting is to be held, which place shall be spe cified in the notice of the meeting, or, if not so specified, at the place where the meeting is to be held.   The list shall also be produced and kept at the time and place of the meeting during the entire duration thereof, and may be inspected by any Stockholder who is present.
 
Section 2.09   Judges.   If at any meeting of the Stockholders a vote by written ballot shall be taken on any question, the chairman of such meeting may appoint a judge or judges to act with respect to such vote.   Each judge so appointed shall first subscribe an oath faithfully to execute the duties of a judge at such meeting with strict impartiality and according to the best of his or her ability.   Such judges shall decide upon the qualification of the voters and shall report the number of shares represented at the meeting and entitled to vote on such question, shall conduct and accept the votes, and, when the v oting is completed shall ascertain and report the number of shares voted respectively for and against the question.   Reports of the judges shall be in writing and subscribed and delivered by them to the Secretary.  The judges need not be Stockholders of the Corporation, and any officer of the Corporation may be a judge on any question other than a vote for or against a proposal in which he or she shall have a material interest.
 
Section 2.10.   Disclosure of Certain Interests.  (a)  Any Person that, as of the date of the Public Announcement of the adoption of these Bylaws, is the Beneficial Owner of Voting Stock or, in connection with any acquisition or disposition of Beneficial Ownership of any Voting Stock of the Corporation on or after the date of the Public Announcement of the adoption of these Bylaws, (i) is required to file a Schedule 13D (or any successor form) or an amendment thereto with the Securities and Exchange Commission or (ii) would be required to file a Schedule 13D (or any successor form) or an amendment thereto with the Securities and Exchange C ommission if (x) the definition of Beneficial Ownership herein was substituted for the determination of “beneficial ownership” set forth in Rule 13d-3 under the Exchange Act and (y) any reference to the phrase “more than five percent” set forth in Rule 13d under the Exchange Act was substituted and replaced with the phrase “more than seven and one-half percent”, shall, in either case, within 20 days after the date of the Public Announcement of the adoption of these Bylaws or, in all other cases, as promptly as practicable, but within 10 business days, after the date of any such acquisition or disposition or any change in a material fact set forth in a statement previously provided to the Corporation, as the case may be, deliver to the Corporation a statement containing (A) the information that would be required to be filed on such Schedule 13D (including the exhibits thereto) or such amendment, as the case may be, if (x) the definition of Beneficial Ownership her ein was substituted for the determination of “beneficial ownership” set forth in Rule 13d-3 under the Exchange Act and (y) any reference to the phrase “more than five percent” set forth in Rule 13d under the Exchange Act was substituted and replaced with the phrase “more than seven and one-half percent”, (B) a list of all Derivative Interests of such Person and (C) a description of all economic terms of all such Derivative Interests and copies of all agreements and other documents (including but not limited to master agreements, confirmations and all ancillary documents and the names and details of all counterparties to, and brokers involved in, all such transactions) relating to each such Derivative Interest.
 
       (b)  A Person shall be deemed the “Beneficial Owner” of, shall be deemed to “Beneficially Own” and shall be deemed to have “Beneficial Ownership” of, any Voting Stock (i) that such Person or any of such Person’s Affiliates or Associates (as defined under Regulation 12B under the Exchange Act or any successor provision thereto) is deemed to “beneficially own” within the meaning of Section 13(d) of, and Regulation 13D under, the Exchange Act or any successor provision thereto, or (ii) that is the subject of, or the reference security for or that underlies any Derivative Interest of such Person or any of such Person’s Affiliates or Associates (as defined under Regulation 12B under the Exchange Act or any successor provision thereto), with the number of shares of Voting Stock deemed Beneficially Owned being the notional or other number of shares of Voting Stock specified in the documentation evidencing the Derivative Interest as being subject to be acquired upon the exercise or settlement of the Derivative Interest or as the basis upon which the value or settlement amount of such Derivative Interest is to be calculated in whole or in part or, if no such number of shares of Voting Stock is specified in such documentation, as determined by the Board in good faith to be the number of shares of Voting Stock to which the Derivative Interest relates.  When two or more Persons act as a partnership, limited partnership, syndicate, or other group, or otherwise act in concert, in each case, for the purpose of acquiring, holding, or disposing of securities of the Corpora tion or for the purpose of proposing one or more Stockholder Nominees, putting forward any other proposal for consideration or voting together on any matter presented at a Stockholder meeting, such syndicate or group shall be deemed a “Person” for the purpose of this Section 2.10.  In addition, any Person who, directly or indirectly, creates or uses a trust, proxy, power of attorney, pooling arrangement or any contract, arrangement, or device with the purpose or effect of divesting such Person of Beneficial Ownership of any Voting Stock or preventing the vesting of such Beneficial Ownership as part of a plan or scheme to evade the reporting requirements of Section 2.04 or this Section 2.10 shall be deemed for the purposes of these Bylaws to be the Beneficial Owner of such Voting Stock.
 
(c)  The Board shall determine whether any Person has satisfied the requirements set forth in this Section 2.10 and such determination shall be binding on the Corporation and the Stockholders.
 
ARTICLE III
 
BOARD OF DIRECTORS
 
Section 3.01   General Powers.   The property, business and affairs of the Corporation shall be managed by the Board.
 
Section 3.02   Number.   The authorized number of directors of the Corporation shall be ten and such authorized number shall not be changed except by a Bylaw or amendment thereof duly adopted by the Stockholders in accordance with the Certificate of Incorporation or by the Board amending this Section 3.02.  However, no decrease in the number of directors constituting the Board shall shorten the term of any incumbent director.  Each director and nominee for election as a director of the Corporation must, as a qualification to serve as a director, deliver to the Secretary at the principal office of the Corporation a written qu estionnaire with respect to the background and qualifications of such person (which questionnaire shall be provided by the Secretary upon written request and approved from time to time by the Board or the Board’s nomination and corporate governance committee) and a written representation and agreement (in the form provided by the Secretary upon written request) (the “Agreement”), which Agreement (i) shall provide that such person (A) is not and will not become a party to (1) any agreement, arrangement or understanding with, and has not given any commitment or assurance to, any person or entity as to how such person, if such person is at the time a director or is subsequently elected as a director of the Corporation, will act or vote on any issue or question (a “Voting Commitment”) that has not been disclosed in writing to the Corporation or (2) any Voting Commitment that could limit or interfere with such person’s ability to comply, if such person is at the time a director or is subsequently elected as a director of the Corporation, with such person’s duties as a director under applicable law, (B) is not and will not become a party to any agreement, arrangement or understanding (whether written or oral) with any person or entity other than the Corporation with respect to any direct or indirect compensation, reimbursement or indemnification in connection with service or action as a director that has not been disclosed in writing to the Corporation, and (C) would be in compliance, if elected as a director of the Corporation, and will, if such person is at the time a director or is subsequently elected as director of the Corporation, comply with all applicable corporate governance, conflict of interest, confidentiality and securities ownership and trading policies and guidelines of the Corporation (copies of which shall be provided by the Secretary upon written request) (subject to any waivers or exemptions granted pursuant to a resolution of the majority of the disinterested members of the Board) and (ii) if such person is at the time a director or is subsequently elected as a director of the Corporation, shall include such person’s irrevocable resignation as a director if such person is found by a court of competent jurisdiction to have breached the Agreement in any material respect.
 
Section 3.03   Election of Directors.   The directors shall be elected by the Stockholders of the Corporation.  The election of directors is subject to any provisions contained in the Certificate of Incorporation relating thereto, including any provisions for cumulative voting.  A nominee for director shall be elected to the Board if the votes cast for such nominee's election exceed the votes cast against such nominee's election; provided, however, that directors shall be elected by a plurality of the votes cast at any meeting of the Stockholders for which (i ) the Secretary receives a notice that a Stockholder has nominated a person for election to the Board in compliance with the advance notice requirements for Stockholder Nominees for director set forth in Article II, Section 2.04
 
of these Bylaws and (ii) such nomination has not been withdrawn by such Stockholder on or prior to the tenth day preceding the date the Corporation first mails its notice of meeting for such meeting to the Stockholders (a “contested election”).  If directors are to be elected by a plurality of the votes cast, the Stockholders shall not be permitted to vote against a nominee.  The Board has established procedures set forth in the Corporate Governance Guidelines under which in any non-contested election of directors, any incumbent director nominee who receives a greater number of votes cast against his or her election than in favor of his or her election shall tender his or her resignation, and the Board shall decide, through a process managed by the Committee (as defined in the Corporate Governance Guidelines) whether to accept or reject the resignation, or whether other action should be taken.  Any vacancy resulting from the non-election of a director under this Section 3.03 may be filled by the Board as provided in Section 3.06.
 
Section 3.04   Mandatory Retirement.  Each director of the Corporation serving at age 74 shall retire from the Board at the end of the calendar year in which his or her 74th birthday occurs, except for directors serving on the Board at January 1, 2006, and provided that the Board may approve one exemption at any time for directors who joined the Board after such date.   For purposes of this Section, “end of the calendar year” shall include the period ending with the seventh day of January next following.
 
Section 3.05   Resignations.   Any director of the Corporation may resign at any time by giving written notice to the Board or to the Secretary.   Any such resignation shall take effect at the time specified therein, or, if the time be not specified, it shall take effect immediately upon its receipt; and, unless otherwise specified therein, the acceptance of such resignation shall not be necessary to make it effective.
 
Section 3.06   Vacancies.   Except as otherwise provided in the Certificate of Incorporation, any vacancy in the Board, whether because of death, resignation, disqualification, non-election pursuant to Section 3.03, an increase in the number of directors, or any other cause, may be filled by vote of the majority of the remaining directors, although less than a quorum.   Each director so chosen to fill a vacancy shall hold office until his or her successor shall have been elected and shall qualify or until he or she shall resign or shall have been removed. 
 
Section 3.07   Place  of  Meeting,  etc.   The Board may hold any of its meetings at such place or places within or without the State of Delaware as the Board may from time to time by resolution designate or as shall be designated by the person or persons calling the meeting or in the notice or a waiver of notice of any such meeting.   Directors may participate in any regular or special meeting of the Board by means of conference telephone or similar communications equipment pursuant to which all persons participating in the meeting of the Board can hear each other, and such participation shall constitute presence in person at such meeting.
 
Section 3.08   First  Meeting.   The Board shall meet as soon as practicable after each annual election of directors and notice of such first meeting shall not be required.
 
Section 3.09   Regular  Meetings.   Regular meetings of the Board may be held at such times as the Board shall from time to time by resolution determine.   If any day fixed for a meeting shall be a legal holiday at the place where the meeting is to be held, then the meeting shall be held at the same hour and place on the next succeeding business day not a legal holiday.   Except as provided by law, notice of regular meetings need not be given.
 
Section 3.10   Special  Meetings.   Special meetings of the Board may be called at any time by the Chairman or the President or by any two directors, to be held at the principal office of the Corporation, or at such other place or places, within or without the State of Delaware, as the person or persons calling the meeting may designate.
 
Notice of all special meetings of the Board shall be given to each director by two days' service of the same by telegram, by letter, or personally.   Such notice may be waived by any director and any meeting shall be a legal meeting without notice having been given if all the directors shall be present thereat or if those not present shall, either before or after the meeting, sign a written waiver of notice of, or a consent to, such meeting or shall after the meeting sign the approval of the minutes thereof.   All such waivers, consents or approvals shall be filed with the corporate records or be made a part of the minutes of the meeting.
 
Section 3.11   Quorum  and  Manner  of  Acting.   Except as otherwise provided in the Bylaws or by law, the presence of a majority of the authorized number of directors shall be required to constitute a quorum for the transaction of business at any meeting of the Board, and all matters shall be decided at any such meeting, a quorum being present, by the affirmative votes of a majority of the directors present.   In the absence of a quorum, a majority of directors present at any meeting may adjourn the same from time to time until a quorum shall be present.   Notice of any adjourned meeting need not be given.   The directors shall act only as a Board, and the individual directors shall have no power as such. 
 
Section 3.12   Action by Consent.   Any action required or permitted to be taken at any meeting of the Board or of any committee thereof may be taken without a meeting if a written consent thereto is signed by all members of the Board or of such committee, as the case may be, and such written consent is filed with the minutes of proceedings of the Board or such committee.
 
       Section 3.13   Compensation.   No stated salary need be paid directors, as such, for their services, but, by resolution of the Board, a fixed sum and expenses of attendance, if any, may be allowed for attendance at each regular or special meeting of the Board or an annual directors’ fee may be paid; provided that nothing herein contained shall be construed to preclude any director from serving the Corporation in any other capacity and receiving compensation therefor.   Members of special or standing committees may be allowed like compensation for attending committee meetings.
 
Section 3.14   Committees.   The Board may, by resolution passed by the Board, designate one or more committees, each committee to consist of one or more of the directors of the Corporation.  Except as otherwise provided in the Board resolution designating a committee, the presence of a majority of the authorized number of members of such committee shall be required to constitute a quorum for the transaction of business at any meeting of such committee.   Any such committee, to the extent provided in the resolution of the Board, shall have and may exercise all the powers and authority of the Board in the management of the bu siness and affairs of the Corporation, and may authorize the seal of the Corporation to be affixed to all papers which may require it; but no such committee shall have any power or authority in reference to amending the Certificate of Incorporation, adopting an agreement of merger or consolidation, recommending to the Stockholders the sale, lease or exchange of all or substantially all of the Corporation's property and assets, recommending to the Stockholders a dissolution of the Corporation or a revocation of the dissolution, or amending the Bylaws of the Corporation; and unless the resolution of the Board expressly so provides, no such committee shall have the power or authority to declare a dividend or to authorize the issuance of stock.   Any such committee shall keep written minutes of its meetings and report the same to the Board at the next regular meeting of the Board.
 
Section 3.15   Officers of the Board.   The Board shall have a Chairman and may, at the discretion of the Board, have a Vice Chairman and other officers.   The Chairman of the Board and the Vice Chairman shall be appointed from time to time by the Board, unless such positions are elected offices of the Corporation, currently filled, and shall have such powers and duties as shall be designated by the Board. 
 

 
ARTICLE IV
 
OFFICERS
 
Section 4.01   Officers.   The officers of the Corporation shall be a Chairman, a Chief Executive Officer, a Secretary, a Treasurer and such other officers as may be appointed by the Board as the business of the Corporation may require.   Officers shall have such powers and duties as are permitted or required by law or as may be specified by or in accordance with resolutions of the Board.   Any number of offices may be held by the same person.  Unless the Board shall otherwise determine, the Chairman shall be the Chief Executive Officer of the Corporation.   In the absence of any contrary determ ination by the Board, the Chief Executive Officer shall, subject to the power and authority of the Board, have general supervision, direction and control of the officers, employees, business and affairs of the Corporation.
 
Section 4.02   Election and Term.   The officers of the Corporation shall be elected annually by the Board.   The Board may at any time and from time to time elect such additional officers as the business of the Corporation may require.   Each officer shall hold his or her office until his or her successor is elected and qualified or until his or her earlier resignation or removal.
 
Section 4.03   Removal and Resignation.   Any officer may be removed, either with or without cause, by a majority of the directors at the time in office, at any regular or special meeting of the Board. Any officer may resign at any time by giving notice to the Board.   Such resignation shall take effect at the time specified in such notice or, in the absence of such specification, at the date of the receipt by the Board of such notice.   Unless otherwise specified in such notice, the acceptance of such resignation shall not be necessary to make it effective.
 
Section 4.04   Vacancies.   Any vacancy occurring in any office of the Corporation by death, resignation, removal or otherwise, shall be filled in the manner prescribed in these Bylaws for the regular appointment to such office. 
 
ARTICLE V
 
CONTRACTS, CHECKS, DRAFTS, BANK ACCOUNTS, ETC.
 
Section 5.01   Execution  of  Contracts.   The Board, except as in the Bylaws otherwise provided, may authorize any officer or officers, agent or agents, to enter into any contract or execute any instrument in the name and on behalf of the Corporation, and such authority may be general or confined to specific instances; and unless so authorized by the Board or by the Bylaws, no officer, agent or employee shall have any power or authority to bind the Corporation by any contract or engagement or to pledge its credit or to render it liable for any purpose or in any amount.
 
       Section 5.02   Checks,  Drafts,  etc.   All checks, drafts or other orders for payment of money, notes or other evidence of indebtedness, issued in the name of or payable to the Corporation, shall be signed or endorsed by such person or persons and in such manner as, from time to time, shall be determined by resolution of the Board.   Each such person shall give such bond, if any, as the Board may require.
 
Section 5.03   Deposit.   All funds of the Corporation not otherwise employed shall be deposited from time to time to the credit of the Corporation in such banks, trust companies or other depositories as the Board may select, or as may be selected by any officer or officers, assistant or assistants, agent or agents, or attorney or attorneys of the Corporation to whom such power shall have been delegated by the Board.   For the purpose of deposit and for the purpose of collection for the account of the Corporation, the Chief Executive Officer, the President or the Treasurer (or any other officer or officers, assistant or assistant s, agent or agents, or attorney or attorneys of the Corporation who shall from time to time be determined by the Board) may endorse, assign and deliver checks, drafts and other orders for the payment of money which are payable to the order of the Corporation.
 
Section 5.04   General  and  Special  Bank  Accounts.   The Board may from time to time authorize the opening and keeping of general and special bank accounts with such banks, trust companies or other depositories as the Board may select or as may be selected by any officer or officers, assistant or assistants, agent or agents, or attorney or attorneys of the Corporation to whom such power shall have been delegated by the Board.   The Board may make such special rules and regulations with respect to such bank accounts, not inconsistent with the provisions of the Bylaws, as it may deem expedient. 
 
ARTICLE VI
 
SHARES AND THEIR TRANSFER
 
Section 6.01   Certificates  for  Stock.   Every owner of stock of the Corporation shall be entitled to have a certificate or certificates, to be in such form as the Board shall prescribe, certifying the number and class of shares of the stock of the Corporation owned by him or her. The certificates representing shares of such stock shall be numbered in the order in which they shall be issued and shall be signed in the name of the Corporation by the President and by the Secretary.   Any or all of the signatures on the certificates may be a facsimile.   In case any officer, transfer agent or registrar who has signed or whose facsimile signature has been placed upon any such certificate shall thereafter have ceased to be such officer, transfer agent or registrar before such certificate is issued, such certificate may nevertheless be issued by the Corporation with the same effect as though the person who signed such certificate, or whose facsimile signature shall have been placed thereupon, were such officer, transfer agent or registrar at the date of issue.   A record shall be kept of the respective names of the persons, firms or corporations owning the stock represented by such certificates, the number and class of shares represented by such certificates, respectively, and the respective dates thereof, and in case of cancellation the respective dates of cancellation.   Every certificate surrendered to the Corporation for exchange or transfer shall be cancelled, and no new certificate or certificates shall be issued in exchange for any existing certificate until such existing cert ificate shall have been so cancelled, except in cases provided for in Section 6.04 of the Bylaws.
 
Section 6.02   Transfers of Stock.   Transfers of shares of stock of the Corporation shall be made only on the books of the Corporation by the registered holder thereof, or by his or her attorney thereunto authorized by power of attorney duly executed and filed with the Secretary, or with a transfer clerk or a transfer agent appointed as provided in Section 6.03 of the Bylaws, and upon surrender of the certificate or certificates for such shares properly endorsed and the payment of all taxes thereon.   The person in whose name shares of stock stand on the books of the Corporation shall be deemed the owner thereof for all pur poses as regards the Corporation.   Whenever any transfer of shares shall be made for collateral security, and not absolutely, such fact shall be stated expressly in the entry of transfer if, when the certificate or certificates shall be presented to the Corporation for transfer, both the transferor and the transferee request the Corporation to do so.
 
Section 6.03   Regulations.   The Board may make such rules and regulations as it may deem expedient, not inconsistent with the Bylaws, concerning the issue, transfer and registration of certificates for shares of the stock of the Corporation.   It may appoint, or authorize any officer or officers to appoint, one or more transfer clerks or one or more transfer agents and one or more registrars, and may require all certificates for stock to bear the signature or signatures of any of them.
 
Section 6.04   Lost, Stolen, Destroyed, And Mutilated Certificates.   In any case of loss, theft, destruction, or mutilation of any certificate of stock, another may be issued in its place upon proof of such loss, theft, destruction, or mutilation and upon the giving of a bond of indemnity to the Corporation in such form and in such sum as the Board may direct; provided, however, that a new certificate may be issued without requiring any bond when, in the judgment of the Board, it is proper so to do.
 
Section 6.05   Fixing  Date  for  Determination  of  Stockholders of  Record.   In order that the Corporation may determine the Stockholders entitled to notice of or to vote at any meeting of the Stockholders or any adjournment thereof, or entitled to receive payment of any dividend or other distribution or allotment of any rights, or entitled to exercise any rights in respect of any other change, conversion or exchange of stock or for the purpose of any other lawful action, the Board may fix, in advance, a record date, which shall not be more than 60 nor less than 10 days before the date of such meeting, nor more than 60 days prior to any other
 
action.   If, in any case involving the determination of the Stockholders for any purpose other than notice of or voting at a meeting of the Stockholders, the Board shall not fix such a record date, the record date for determining the Stockholders for such purpose shall be the close of business on the day on which the Board shall adopt the resolution relating thereto.   A determination of the Stockholders entitled to notice of or to vote at a meeting of the Stockholders shall apply to any adjournment of such meeting; provided, however, that the Board may fix a new record date for the adjourned meeting. 
 
ARTICLE VII

MISCELLANEOUS

Section 7.01   Seal.   The Board shall provide a corporate seal, which shall be in the form of a circle and shall bear the name of the Corporation and words and figures showing that the Corporation was incorporated in the State of Delaware and the year of incorporation.
 
Section 7.02   Waiver  of  Notices.   Whenever notice is required to be given by the Bylaws or the Certificate of Incorporation or by law, the person entitled to said notice may waive such notice in writing, either before or after the time stated therein, and such waiver shall be deemed equivalent to notice.
 
Section 7.03   Fiscal Year.   The fiscal year of the Corporation shall end on the 31st day of December of each year.
 
Section 7.04   Amendments.   The Bylaws, or any of them, may be rescinded, altered, amended or repealed, and new Bylaws may be made, (i) by the Board, by vote of a majority of the number of directors then in office as directors, acting at any meeting of the Board, or (ii) by the vote of the holders of not less than a majority of the total voting power of all outstanding shares of voting stock of the Corporation, at any annual meeting or special meeting of the Stockholders, provided that notice of such proposed amendment, modification, repeal or adoption is given in accordance with the notice provisions set forth in Section 2.04 herein.  60; Any Bylaws made or altered by the Stockholders may be altered or repealed by the Board or may be altered or repealed by the Stockholders. 
 
 

EX-99.1 7 exhibit99.htm EX-99.1 exhibit99.htm

 
Exhibit 99.1
   
Pending Legal Actions before the Federal Mine Safety and Health Review Commission
   
Mine Name
Docket Number
#1 Prep Plant (Sidney)
KENT 2008-757
#1 Prep Plant (Sidney)
KENT 2008-862
#1 Prep Plant (Sidney)
KENT 2009-1499
#1 Prep Plant (Sidney)
KENT 2010-313
#1 Prep Plant (Sidney)
KENT 2010-352
#1 Prep Plant (Sidney)
KENT 2010-353
#1 Prep Plant (Sidney)
KENT 2010-48
#1 Prep Plant (Sidney)
KENT 2010-551
Alex Energy Inc.
N/A
Allegiance Mine
WEVA 2008-1286
Allegiance Mine
WEVA 2008-1844
Allegiance Mine
WEVA 2008-756
Allegiance Mine
WEVA 2009-1069
Allegiance Mine
WEVA 2009-1277
Allegiance Mine
WEVA 2009-1427
Allegiance Mine
WEVA 2009-1657
Allegiance Mine
WEVA 2009-1658
Allegiance Mine
WEVA 2009-1803
Allegiance Mine
WEVA 2009-474
Allegiance Mine
WEVA 2009-475
Allegiance Mine
WEVA 2009-645
Allegiance Mine
WEVA 2009-646
Allegiance Mine
WEVA 2009-819
Allegiance Mine
WEVA 2009-971
Allegiance Mine
WEVA 2010-330
Allegiance Mine
WEVA 2010-456
Allegiance Mine
WEVA 2010-584
Allegiance Mine
WEVA 2010-841
Allegiance Mine
WEVA 2010-968
Allen Powellton Mine
WEVA 2008-717
Allen Powellton Mine
WEVA 2009-1054
Allen Powellton Mine
WEVA 2009-1422
Allen Powellton Mine
WEVA 2009-270
Allen Powellton Mine
WEVA 2009-271
Allen Powellton Mine
WEVA 2009-631
Allen Powellton Mine
WEVA 2009-910
Aracoma Alma Mine #1
WEVA 2009-1944 WEVA 2009-1377-R WEVA 2009-1378-R
Aracoma Alma Mine #1
WEVA 2010-1162
Aracoma Alma Mine #1
WEVA 2010-267
Aracoma Alma Mine #1
N/A
Aracoma Alma Mine #1
N/A
Bent Branch Energy Co Mine No 1
KENT 2010-132
Black Castle Mining Co
WEVA 2007-421 WEVA 2007-288
Black Castle Mining Co
WEVA 2008-1370
Black Castle Mining Co
WEVA 2009 -1453
Black Castle Mining Co
WEVA 2009-1581
Black Castle Mining Co
WEVA 2009-1717
Black Castle Mining Co
WEVA 2009-681
Black Castle Mining Co
WEVA 2009-851
Black King I North Portal
WEVA 2008-1101
Black King I North Portal
WEVA 2008-1102
Black King I North Portal
WEVA 2008-112
Black King I North Portal
WEVA 2008-1541
Black King I North Portal
WEVA 2009-110
Black King I North Portal
WEVA 2009-1293
Black King I North Portal
WEVA 2009-1485, -1486 (including contests WEVA 2009-1189R through 1243R)
Black King I North Portal
WEVA 2009-1767
Black King I North Portal
WEVA 2009-615
Black King I North Portal
WEVA 2009-781
Black Knight II
WEVA 2008-1116
Black Knight II
WEVA 2008-1336
Black Knight II
WEVA 2008-1538
Black Knight II
WEVA 2008-1539
Black Knight II
WEVA 2009-1114
Black Knight II
WEVA 2009-1298
Black Knight II
WEVA 2009-1515
Black Knight II
WEVA 2009-1766
Black Knight II
WEVA 2009-1821
Black Knight II
WEVA 2009-1822
Black Knight II
WEVA 2009-479
Black Knight II
WEVA 2009-480
Black Knight II
WEVA 2009-616
Black Knight II
WEVA 2009-617
Black Knight II
WEVA 2009-804
Black Knight II
WEVA 2009-94
Blue Pennant Transfer
WEVA 2009-1538
Brushy Eagle
WEVA 2008-1128
Brushy Eagle
WEVA 2009-1046
Brushy Eagle
WEVA 2009-1421
Brushy Eagle
WEVA 2009-1886
Brushy Eagle
WEVA 2009-268
Brushy Eagle
WEVA 2009-459
Brushy Eagle
WEVA 2009-625
Brushy Eagle
WEVA 2009-718
Brushy Eagle
WEVA 2009-903
Camp Branch Mine
WEVA 2007-774
Camp Branch Mine
WEVA 2008-1152
Camp Branch Mine
WEVA 2008-1326
Camp Branch Mine
WEVA 2008-938
Camp Branch Mine
WEVA 2009-694
Camp Branch Mine
WEVA 2009-695
Castle East Portal
WEVA 2008-434
Castle East Portal
WEVA 2008-555
Castle East Portal
WEVA 2009-32
Castle Mine
WEVA 2008-1545
Castle Mine
WEVA 2008-1547
Castle Mine
WEVA 2008-382
Castle Mine
WEVA 2009-1112
Castle Mine
WEVA 2009-1305
Castle Mine
WEVA 2009-1572
Castle Mine
WEVA 2009-1764
Castle Mine
WEVA 2009-511
Castle Mine
WEVA 2009-583
Castle Mine
WEVA 2009-826
Castle Mine
WEVA 2010-503
Chess Processing
WEVA 2009-476
Chess Processing
WEVA 2009-477
Chess Processing
WEVA 2009-598
Chess Processing
WEVA 2009-776
Chesterfield Prep Plant
WEVA 2008-1277
Chesterfield Prep Plant
WEVA 2009-1315
Chesterfield Prep Plant
WEVA 2009-1800
Chesterfield Prep Plant
WEVA 2009-395
Chesterfield Prep Plant
WEVA 2009-472
Chesterfield Prep Plant
WEVA 2009-473
Coon Cedar Grove Mine
WEVA 2008-1126
Coon Cedar Grove Mine
WEVA 2008-1187
Coon Cedar Grove Mine
WEVA 2008-1639
Coon Cedar Grove Mine
WEVA 2008-720
Coon Cedar Grove Mine
WEVA 2009-1425
Coon Cedar Grove Mine
WEVA 2009-627
Coon Cedar Grove Mine
WEVA 2009-628
Coon Cedar Grove Mine
WEVA 2009-907
Delbarton Preparation Plant
WEVA 2008-1052
Delbarton Preparation Plant
WEVA 2008-1053
Delbarton Preparation Plant
WEVA 2008-1317
Delbarton Preparation Plant
WEVA 2008-309
Delbarton Preparation Plant
WEVA 2009-162
Diamond Energy
WEVA 2009-1268
Diamond Energy
WEVA 2009-1458
Diamond Energy
WEVA 2009-149
Diamond Energy
WEVA 2009-150
Diamond Energy
WEVA 2009-1535
Diamond Energy
WEVA 2009-1641
Diamond Energy
WEVA 2009-340
Diamond Energy
WEVA 2009-341
Diamond Energy
WEVA 2009-494
Diamond Energy
WEVA 2009-713
Diamond Energy
WEVA 2009-714
Diamond Energy
WEVA 2010-858
Diamond Energy
WEVA 2010-858
Edwight Surface Mine
WEVA 2008-1776
Edwight Surface Mine
WEVA 2009-1644
Edwight Surface Mine
WEVA 2009-1763
Edwight Surface Mine
WEVA 2009-662
Emily Creek Energy
KENT 2010-1495
Fraley Branch Surface Mine
KENT 2008-1439
Fraley Branch Surface Mine
KENT 2008-442
Fraley Branch Surface Mine
KENT 2008-443
Fraley Branch Surface Mine
KENT 2008-552
Fraley Branch Surface Mine
KENT 2009-1472
Fraley Branch Surface Mine
KENT 2010-55
Freeze Fork Surface Mine
WEVA 2008-1250
Freeze Fork Surface Mine
WEVA 2008-468
Freeze Fork Surface Mine
WEVA 2008-469
Freeze Fork Surface Mine
WEVA 2008-618
Freeze Fork Surface Mine
WEVA 2009-110
Freeze Fork Surface Mine
WEVA 2009-1121
Freeze Fork Surface Mine
WEVA 2009-1497
Freeze Fork Surface Mine
WEVA 2009-1882
Freeze Fork Surface Mine
WEVA 2009-688
Freeze Fork Surface Mine
WEVA 2009-689
Freeze Fork Surface Mine
WEVA 2009-829;   WEVA 2008-727-R thru 2008-729-R
Freeze Fork Surface Mine
WEVA 2009-935
Grassy Creek No 1
WEVA 2008-1470
Grassy Creek No 1
WEVA 2008-606
Grassy Creek No 1
WEVA 2009-1161
Grassy Creek No 1
WEVA 2009-1162
Grassy Creek No 1
WEVA 2009-1314
Grassy Creek No 1
WEVA 2009-1383
Grassy Creek No 1
WEVA 2009-1559
Grassy Creek No 1
WEVA 2009-1709
Grassy Creek No 1
WEVA 2009-1809
Grassy Creek No 1
WEVA 2009-1810
Grassy Creek No 1
WEVA 2009-258
Grassy Creek No 1
WEVA 2009-361
Grassy Creek No 1
WEVA 2009-362
Grassy Creek No 1
WEVA 2009-478
Grassy Creek No 1
WEVA 2009-668
Grassy Creek No 1
WEVA 2010-1018
Grassy Creek No 1
WEVA 2010-1720
Green Valley Trucking
WEVA 2008-1122
Guyandotte Energy Slope Mine #2
N/A
Guyandotte Energy Slope Mine #2
N/A
Hatfield Energy Mine
WEVA 2009-1536
Hatfield Energy Mine
WEVA 2009-1619
Hernshaw Mine
WEVA 2009-1677
Highland Coal Handling Facility
WEVA 2008-1160
Highland Coal Handling Facility
WEVA 2009-1037
Homer III Processing
WEVA 2008-1894
Homer III Processing
WEVA 2009-1435
Hominy Creek Mine
WEVA 2009-1165
Hominy Creek Mine
WEVA 2009-1166
Hominy Creek Mine
WEVA 2009-670
Horse Creek Eagle
WEVA 2008-1130
Horse Creek Eagle
WEVA 2008-1460
Horse Creek Eagle
WEVA 2008-719
Horse Creek Eagle
WEVA 2009-1053
Horse Creek Eagle
WEVA 2009-1308   WEVA 2009-1309
Horse Creek Eagle
WEVA 2009-1426
Horse Creek Eagle
WEVA 2009-630
Horse Creek Eagle
WEVA 2010-517
Hunter Peerless Mine
WEVA 2009-1505
Hunter Peerless Mine
WEVA 2009-1582
Jerry Fork Eagle
WEVA 2008-1124
Jerry Fork Eagle
WEVA 2008-1481
Jerry Fork Eagle
WEVA 2008-1786
Jerry Fork Eagle
WEVA 2009-1127
Jerry Fork Eagle
WEVA 2009-1336
Jerry Fork Eagle
WEVA 2009-1549
Jerry Fork Eagle
WEVA 2009-246
Jerry Fork Eagle
WEVA 2009-587
Jerry Fork Eagle
WEVA 2009-588
Jerry Fork Eagle
WEVA 2009-955
Justice #1
WEVA 2007-582
Justice #1
WEVA 2008-1288
Justice #1
WEVA 2008-1848
Justice #1
WEVA 2009-1068
Justice #1
WEVA 2009-1275
Justice #1
WEVA 2009-1276
Justice #1
WEVA 2009-1465
Justice #1
WEVA 2009-1649
Justice #1
WEVA 2009-1802
Justice #1
WEVA 2009-1889
Justice #1
WEVA 2009-290
Justice #1
WEVA 2009-291
Justice #1
WEVA 2009-470
Justice #1
WEVA 2009-471
Justice #1
WEVA 2009-639
Justice #1
WEVA 2009-643
Justice #1
WEVA 2009-824
Justice #1
WEVA 2009-981
Justice #1
WEVA 2009-982
Justice #1
WEVA 2010-1234
Justice #1
WEVA 2010-697
Justice #1
WEVA 2010-836
Laurel Coalburg Tunnel Mine
WEVA 2009-1848
Laurel Coalburg Tunnel Mine
WEVA 2009-855
Laurel Creek/Spirit Mine
WEVA 2007-663
Laurel Creek/Spirit Mine
WEVA 2007-664
Liberty Processing
WEVA 2008-1820
Liberty Processing
WEVA 2009-1645
Liberty Processing
WEVA 2009-822
Liberty Processing
WEVA 2009-823
Liberty Processing
WEVA 2009-969
Liberty Processing
WEVA 2010-1128
Liberty Processing
WEVA 2010-1215
Long Fork Preparation Plant
KENT 2008-1011
Long Fork Preparation Plant
KENT 2008-633
Long Fork Preparation Plant
KENT 2009-1339
Long Fork Preparation Plant
KENT 2009-180
Long Fork Preparation Plant
KENT 2009-374
Long Fork Preparation Plant
KENT 2009-375
Long Fork Preparation Plant
KENT 2010-1161
Long Fork Preparation Plant
KENT 2010-1162
Long Fork Preparation Plant
KENT 2010-1234
Long Fork Preparation Plant
KENT 2010-1235
Long Fork Preparation Plant
KENT 2010-1236
Long Fork Preparation Plant
KENT 2010-1409
Long Fork Preparation Plant
KENT 2010-1410
Long Fork Preparation Plant
KENT 2010-169
Long Fork Preparation Plant
KENT 2010-30
Long Fork Preparation Plant
KENT 2010-31
Long Fork Preparation Plant
KENT 2010-526
Long Fork Preparation Plant
KENT 2010-880
Long Pole Energy Mine
KENT 2010-131
Love Branch Mine
KENT 2008-1012
Love Branch Mine
KENT 2008-1013
Love Branch Mine
KENT 2008-1268
Love Branch Mine
KENT 2009-1035
Love Branch Mine
KENT 2009-1280
Love Branch Mine
KENT 2009-1515
Love Branch Mine
KENT 2009-1516
Love Branch Mine
KENT 2009-99
Love Branch Mine
KENT 2010-1137
Love Branch Mine
KENT 2010-195
Love Branch Mine
KENT 2010-196
Love Branch Mine
KENT 2010-354
Love Branch Mine
KENT 2010-355
Love Branch Mine
KENT 2010-384
Love Branch Mine
KENT 2010-577
Love Branch Mine
KENT 2010-66
Love Branch Mine
KENT 2010-69
Love Branch Mine
KENT 2010-720
Love Branch Mine
KENT 2010-843
Love Branch Mine
KENT 2010-963
Love Branch South
KENT 2009-1446
Love Branch South
KENT 2009-1523-R KENT 2009-1524-R
Mammoth #2 Gas
WEVA  2008-1653
Mammoth #2 Gas
WEVA 2008-1294
Mammoth #2 Gas
WEVA 2008-1654
Mammoth #2 Gas
WEVA 2008-1655
Mammoth #2 Gas
WEVA 2009-1295
Mammoth #2 Gas
WEVA 2009-1296
Mammoth #2 Gas
WEVA 2009-1826
Marfork Processing
WEVA 2009-1047
Marfork Processing
WEVA 2009-1437
Marfork Processing
WEVA 2009-359
Marfork Processing
WEVA 2009-904
Marsh Fork Mine
WEVA 2009-1052
Marsh Fork Mine
WEVA 2009-1317
Marsh Fork Mine
WEVA 2009-1463
Marsh Fork Mine
WEVA 2009-1887
Marsh Fork Mine
WEVA 2009-269
Marsh Fork Mine
WEVA 2009-460
Marsh Fork Mine
WEVA 2009-905
Marsh Fork Mine
WEVA 2009-906
Marsh Fork Mine
WEVA 2010-740
Meade Branch Surface
KENT 2010-1564
Mine #1 (Clean Energy)
KENT 2008-1458
Mine #1 (Clean Energy)
KENT 2008-538
Mine #1 (Clean Energy)
KENT 2009-102
Mine #1 (Clean Energy)
KENT 2009-1040
Mine #1 (Clean Energy)
KENT 2009-1102
Mine #1 (Clean Energy)
KENT 2009-1152
Mine #1 (Clean Energy)
KENT 2009-1274
Mine #1 (Clean Energy)
KENT 2009-1448
Mine #1 (Clean Energy)
KENT 2009-566
Mine #1 (Clean Energy)
KENT 2009-901
Mine #1 (Clean Energy)
KENT 2009-925
Mine #1 (Clean Energy)
KENT 2010-1038
Mine #1 (Clean Energy)
KENT 2010-1168
Mine #1 (Clean Energy)
KENT 2010-1169
Mine #1 (Clean Energy)
KENT 2010-1258
Mine #1 (Clean Energy)
KENT 2010-1443
Mine #1 (Clean Energy)
KENT 2010-1444
Mine #1 (Clean Energy)
KENT 2010-1532
Mine #1 (Clean Energy)
KENT 2010-1533
Mine #1 (Clean Energy)
KENT 2010-177
Mine #1 (Clean Energy)
KENT 2010-178
Mine #1 (Clean Energy)
KENT 2010-304
Mine #1 (Clean Energy)
KENT 2010-49
Mine #1 (Clean Energy)
KENT 2010-50
Mine #1 (Clean Energy)
KENT 2010-552
Mine #1 (Clean Energy)
KENT 2010-553
Mine #1 (Clean Energy)
KENT 2010-750
Mine #1 (Clean Energy)
KENT 2010-966
Mine #1 (Clean Energy)
KENT 2010-967
Mine #1 (Clean Energy)
N/A
Mine #1 (Freedom Energy)
KENT 2008-1019
Mine #1 (Freedom Energy)
KENT 2008-1020
Mine #1 (Freedom Energy)
KENT 2008-1132
Mine #1 (Freedom Energy)
KENT 2008-1133
Mine #1 (Freedom Energy)
KENT 2008-1287
Mine #1 (Freedom Energy)
KENT 2008-1288
Mine #1 (Freedom Energy)
KENT 2008-1399
Mine #1 (Freedom Energy)
KENT 2008-1400
Mine #1 (Freedom Energy)
KENT 2008-1503
Mine #1 (Freedom Energy)
KENT 2008-1503
Mine #1 (Freedom Energy)
KENT 2008-1506
Mine #1 (Freedom Energy)
KENT 2008-1506
Mine #1 (Freedom Energy)
KENT 2008-1531
Mine #1 (Freedom Energy)
KENT 2008-1532
Mine #1 (Freedom Energy)
KENT 2008-1605
Mine #1 (Freedom Energy)
KENT 2008-365
Mine #1 (Freedom Energy)
KENT 2008-366
Mine #1 (Freedom Energy)
KENT 2008-776
Mine #1 (Freedom Energy)
KENT 2008-777
Mine #1 (Freedom Energy)
KENT 2008-778
Mine #1 (Freedom Energy)
KENT 2009-1146
Mine #1 (Freedom Energy)
KENT 2009-1177
Mine #1 (Freedom Energy)
KENT 2009-1297
Mine #1 (Freedom Energy)
KENT 2009-1341
Mine #1 (Freedom Energy)
KENT 2009-1351
Mine #1 (Freedom Energy)
KENT 2009-1371
Mine #1 (Freedom Energy)
KENT 2009-325
Mine #1 (Freedom Energy)
KENT 2009-326
Mine #1 (Freedom Energy)
KENT 2009-670
Mine #1 (Freedom Energy)
KENT 2009-686
Mine #1 (Freedom Energy)
KENT 2009-687
Mine #1 (Freedom Energy)
KENT 2009-705
Mine #1 (Freedom Energy)
KENT 2009-72
Mine #1 (Freedom Energy)
KENT 2009-73
Mine #1 (Freedom Energy)
KENT 2009-785
Mine #1 (Freedom Energy)
KENT 2009-924
Mine #1 (Freedom Energy)
KENT 2010-1069
Mine #1 (Freedom Energy)
KENT 2010-1070
Mine #1 (Freedom Energy)
KENT 2010-1175
Mine #1 (Freedom Energy)
KENT 2010-1259
Mine #1 (Freedom Energy)
KENT 2010-1260
Mine #1 (Freedom Energy)
KENT 2010-1541
Mine #1 (Freedom Energy)
KENT 2010-1542
Mine #1 (Freedom Energy)
KENT 2010-174
Mine #1 (Freedom Energy)
KENT 2010-204
Mine #1 (Freedom Energy)
KENT 2010-358
Mine #1 (Freedom Energy)
KENT 2010-449
Mine #1 (Freedom Energy)
KENT 2010-450
Mine #1 (Freedom Energy)
KENT 2010-565
Mine #1 (Freedom Energy)
KENT 2010-566
Mine #1 (Freedom Energy)
KENT 2010-64
Mine #1 (Freedom Energy)
KENT 2010-65
Mine #1 (Freedom Energy)
KENT 2010-775
Mine #1 (Freedom Energy)
KENT 2010-776
Mine #1 (Freedom Energy)
KENT 2010-924
Mine #1 (Freedom Energy)
KENT 2010-925
Mine #1 (Freedom Energy)
KENT-2010-1352-R
Mine #1 (Freedom Energy)
KENT-2010-1406/KENT-2010-1407
Mine #1 (Freedom Energy)
N/A
Mine #1 (Freedom Energy)
N/A
Mine #1 (Freedom Energy)
N/A
Mine #1 (Freedom Energy)
N/A
Mine #1 (Rockhouse Energy)
KENT 2007-1570
Mine #1 (Rockhouse Energy)
KENT 2007-248
Mine #1 (Rockhouse Energy)
KENT 2007-249
Mine #1 (Rockhouse Energy)
KENT 2007-280
Mine #1 (Rockhouse Energy)
KENT 2007-75
Mine #1 (Rockhouse Energy)
KENT 2008-1273
Mine #1 (Rockhouse Energy)
KENT 2008-1363
Mine #1 (Rockhouse Energy)
KENT 2008-1446
Mine #1 (Rockhouse Energy)
KENT 2008-1618
Mine #1 (Rockhouse Energy)
KENT 2008-970
Mine #1 (Rockhouse Energy)
KENT 2009-1257
Mine #1 (Rockhouse Energy)
KENT 2009-534
Mine #1 (Rockhouse Energy)
KENT 2009-535
Mine #1 (Rockhouse Energy)
KENT 2009-601
Mine #1 (Rockhouse Energy)
KENT 2009-904
Mine #1 (Rockhouse Energy)
KENT 2009-992
Mine #1 (Rockhouse Energy)
KENT 2010-1042
Mine #1 (Rockhouse Energy)
KENT 2010-1174
Mine #1 (Rockhouse Energy)
KENT 2010-1254
Mine #1 (Rockhouse Energy)
KENT 2010-1408
Mine #1 (Rockhouse Energy)
KENT 2010-190
Mine #1 (Rockhouse Energy)
KENT 2010-191
Mine #1 (Rockhouse Energy)
KENT 2010-352
Mine #1 (Rockhouse Energy)
KENT 2010-353
Mine #1 (Rockhouse Energy)
KENT 2010-429
Mine #1 (Rockhouse Energy)
KENT 2010-567
Mine #1 (Rockhouse Energy)
KENT 2010-67
Mine #1 (Rockhouse Energy)
KENT 2010-68
Mine #1 (Rockhouse Energy)
KENT 2010-882
Mine #1 (Rockhouse Energy)
KENT 2010-883
Mine #1 (Rockhouse Energy)
N/A
Mine #1 (Solid Energy)
KENT 2008-1131
Mine #1 (Solid Energy)
KENT 2008-1562
Mine #1 (Solid Energy)
KENT 2008-555
Mine #1 (Solid Energy)
KENT 2009-1268
Mine #1 (Solid Energy)
KENT 2009-620
Mine #1 (Solid Energy)
KENT 2010-1005
Mine #1 (Solid Energy)
KENT 2010-1165
Mine #1 (Solid Energy)
KENT 2010-1237
Mine #1 (Solid Energy)
KENT 2010-198
Mine #1 (Solid Energy)
KENT 2010-199
Mine #1 (Solid Energy)
KENT 2010-312
Mine #1 (Solid Energy)
KENT 2010-424
Mine #1 (Solid Energy)
KENT 2010-532
Mine #1 (Solid Energy)
KENT 2010-63
Mine #1 (Solid Energy)
KENT 2010-881
Mine No 1 (Stillhouse Mining)
KENT 2007-309
Mine No 2 (Big Laurel Mining)
N/A
Mine No 2 (Big Laurel Mining)
N/A
Mine No 2 (Big Laurel Mining)
N/A
Mine No 2 (Big Laurel Mining)
N/A
Mine No 2 (Big Laurel Mining)
VA 2008-118
Mine No 2 (Big Laurel Mining)
VA 2008-119
Mine No 2 (Big Laurel Mining)
VA 2008-35
Mine No 2 (Big Laurel Mining)
VA 2008-67
Mine No 2 (Big Laurel Mining)
VA 2009-146
Mine No 2 (Big Laurel Mining)
VA 2009-233
Mine No 2 (Big Laurel Mining)
VA 2009-276
Mine No 2 (Big Laurel Mining)
VA 2010-174
Mine No 2 (Big Laurel Mining)
VA 2010-175
Mine No 2 (Big Laurel Mining)
VA 2010-292
Mine No 2 (Big Laurel Mining)
VA 2010-604
Mine No 4 (North Fork)
INDICTMENT
Mine No 4 (North Fork)
KENT 2008-1195
Mine No 4 (North Fork)
KENT 2008-1309
Mine No 4 (North Fork)
KENT 2009-1187
Mine No 4 (North Fork)
KENT 2009-1443
Mine No 4 (North Fork)
KENT 2009-605
Mine No 4 (North Fork)
KENT 2009-772
Mine No 5 (Guest Mountain)
VA 2010-150
Mine No 5 (Guest Mountain)
VA 2010-297
Mine No. 1 (Osaka Mining)
N/A
Mine No. 1 (Osaka Mining)
VA 2009-66
Mine No. 1 (Panther Mining)
KENT 2008-1473
Mine No. 4 (Dorchester)
VA 2008-287
Mine No. 4 (Dorchester)
VA 2010-172
Mine No. 4 (Dorchester)
VA 2010-173
Mine No. 4 (Dorchester)
VA 2010-221
MTR Surface Mine
KENT 2010-308
MTR Surface Mine
KENT 2010-425
MTR Surface Mine
KENT 2010-529
MTR Wolf Creek Mine
KENT 2010-1411
MTR Wolf Creek Mine
KENT 2010-1563
MTR Wolf Creek Mine
KENT 2010-317
MTR Wolf Creek Mine
KENT 2010-907
New Ridge Mining Company
KENT 2010-1445
New Ridge Mining Company
KENT 2010-1534
New Ridge Mining Company
KENT 2010-1538
New Ridge Mining Company
KENT 2010-51
No 1 (M 3 Energy)
KENT 2009-1101
No 1 (M 3 Energy)
KENT 2009-1153
No 1 (M 3 Energy)
KENT 2009-1465
No 1 (M 3 Energy)
KENT 2009-1493
No 1 (M 3 Energy)
KENT 2009-1494
No 1 (M 3 Energy)
KENT 2009-674
No 1 (M 3 Energy)
KENT 2009-675
No 1 (M 3 Energy)
KENT 2009-912
No 1 (M 3 Energy)
KENT 2010-1041
No 1 (M 3 Energy)
KENT 2010-1395-R, -1396-R, -1397-R
No 1 (M 3 Energy)
KENT 2010-1405
No 1 (M 3 Energy)
KENT 2010-184
No 1 (M 3 Energy)
KENT 2010-316
No 1 (M 3 Energy)
KENT 2010-33
No 1 (M 3 Energy)
KENT 2010-443
No 1 (M 3 Energy)
KENT 2010-556
No 1 (M 3 Energy)
KENT 2010-58
No 1 (M 3 Energy)
KENT 2010-59
No 1 (M 3 Energy)
KENT 2010-751
No 1 (M 3 Energy)
KENT 2010-919
No 1 Surface (Alex Energy)
N/A
No 1 Surface (Alex Energy)
N/A
No 1 Surface (Alex Energy)
WEVA 2008-1467
No 1 Surface (Alex Energy)
WEVA 2009-1666-R WEVA 2009-1667-R WEVA 2009-1668-R
No 1 Surface (Alex Energy)
WEVA 2009-589
No 1 Surface (Alex Energy)
WEVA 2009-785
No 1 Surface (Alex Energy)
WEVA 2009-873  WEVA 2009-156-R
No 1 Surface (Alex Energy)
WEVA 2009-954
No 130 Mine
WEVA 2007-186
No 130 Mine
WEVA 2007-829
No 130 Mine
WEVA 2008-1207-R      thru 2008-1209-R
No 130 Mine
WEVA 2008-1649
No 130 Mine
WEVA 2008-291
No 130 Mine
WEVA 2008-78
No 130 Mine
WEVA 2009-852
No. 1 (Process Energy)
KENT 2008-1442
No. 1 (Process Energy)
KENT 2008-1443
No. 1 (Process Energy)
KENT 2009-1148
No. 1 (Process Energy)
KENT 2009-1275
No. 1 (Process Energy)
KENT 2009-369
No. 1 (Process Energy)
KENT 2009-917
No. 1 (Process Energy)
KENT 2010-1040
No. 1 (Process Energy)
KENT 2010-1172
No. 1 (Process Energy)
KENT 2010-1338
No. 1 (Process Energy)
KENT 2010-1412
No. 1 (Process Energy)
KENT 2010-1536
No. 1 (Process Energy)
KENT 2010-315
No. 1 (Process Energy)
KENT 2010-442
No. 1 (Process Energy)
KENT 2010-555
No. 1 (Process Energy)
KENT 2010-56
No. 1 (Process Energy)
KENT 2010-57
No. 1 (Process Energy)
KENT 2010-773
No. 1 (Process Energy)
KENT 2010-774
North Surface Mine
WEVA 2009-554
North Surface Mine
WEVA 2009-555
North Surface Mine
WEVA 2009-603
North Surface Mine
WEVA 2009-604
Parker Peerless Mine
WEVA 2009-1381
Parker Peerless Mine
WEVA 2009-1391
Parker Peerless Mine
WEVA 2009-1438
Parker Peerless Mine
WEVA 2009-1693
Parker Peerless Mine
WEVA 2009-1799
Parker Peerless Mine
WEVA 2009-272
Parker Peerless Mine
WEVA 2009-273
Parker Peerless Mine
WEVA 2009-453
Parker Peerless Mine
WEVA 2009-552
Parker Peerless Mine
WEVA 2009-553
Parker Peerless Mine
WEVA 2009-9
Pocahontas Mine
WEVA 2010-1342
Power Mountain Processing
WEVA 2008-980
Power Mountain Processing
WEVA 2010-1116
Preparation Plant (Goals)
WEVA 2008-1050
Preparation Plant (Martin County)
KENT 2010-1559
Preparation Plant (Martin County)
KENT 2010-201
Preparation Plant (Stirrat)
WEVA 2009-154
Preparation Plant (Stirrat)
WEVA 2009-155
Randolph Mine
N/A
Randolph Mine
N/A
Randolph Mine
WEVA 2009-1365
Randolph Mine
WEVA 2009-687
Randolph Mine
WEVA 2009-818
Randolph Mine
WEVA 2009-980
Randolph Mine
WEVA 2010-1014
Randolph Mine
WEVA 2010-1144
Randolph Mine
WEVA 2010-1425
Randolph Mine
WEVA 2010-588
Red Cedar Surface Mine
WEVA 2009-1005
Red Cedar Surface Mine
WEVA 2009-332
Red Cedar Surface Mine
WEVA 2009-853
Red Cedar Surface Mine
WEVA 2009-854
Republic Energy
WEVA 2008-1843
Republic Energy
WEVA 2009-724
Republic Energy
WEVA 2010-563
Right Fork Splint
KENT 2010-1043
River Fork Powellton #1
WEVA 2008-1371
Road Fork #51 Mine
WEVA 2008-1112
Road Fork #51 Mine
WEVA 2009-1065
Road Fork #51 Mine
WEVA 2009-1433
Road Fork #51 Mine
WEVA 2009-1434
Road Fork #51 Mine
WEVA 2009-1442
Road Fork #51 Mine
WEVA 2009-1533
Road Fork #51 Mine
WEVA 2009-1640
Road Fork #51 Mine
WEVA 2009-334
Road Fork #51 Mine
WEVA 2009-335
Road Fork #51 Mine
WEVA 2009-510
Road Fork #51 Mine
WEVA 2009-687
Road Fork #51 Mine
WEVA 2009-691
Road Fork #51 Mine
WEVA 2010-1290
Road Fork #51 Mine
WEVA 2010-890
Round Bottom Surface Mine
KENT 2010-1576
Roundbottom Powellton Deep Mine
WEVA 2008-1307
Roundbottom Powellton Deep Mine
WEVA 2008-1543
Roundbottom Powellton Deep Mine
WEVA 2008-409
Roundbottom Powellton Deep Mine
WEVA 2009-1133
Roundbottom Powellton Deep Mine
WEVA 2009-1337
Roundbottom Powellton Deep Mine
WEVA 2009-1905
Roundbottom Powellton Deep Mine
WEVA 2009-621
Roundbottom Powellton Deep Mine
WEVA 2009-711
Roundbottom Powellton Deep Mine
WEVA 2009-783
Roundbottom Powellton Deep Mine
WEVA 2009-877
Roundbottom Powellton Deep Mine
WEVA 2009-96
Ruby Energy
WEVA 2009-1085
Ruby Energy
WEVA 2009-1086
Ruby Energy
WEVA 2009-1125
Ruby Energy
WEVA 2009-1126
Ruby Energy
WEVA 2009-1353
Ruby Energy
WEVA 2009-1354
Ruby Energy
WEVA 2009-1510
Ruby Energy
WEVA 2009-1511
Ruby Energy
WEVA 2009-1694
Ruby Energy
WEVA 2009-1874
Ruby Energy
WEVA 2009-1942
Ruby Energy
WEVA 2009-403
Ruby Energy
WEVA 2009-697
Ruby Energy
WEVA 2009-698
Ruby Energy
WEVA 2009-821
Ruby Energy
WEVA 2010-1010
Ruby Energy
WEVA 2010-1296
Ruby Energy
WEVA 2010-181
Ruby Energy
WEVA 2010-348 thru 2010-352; WEVA 2010-378-R; WEVA 2010-401-R thru 2010-403; WEVA 2010-512-R
Ruby Energy
WEVA 2010-601
Ruby Energy
WEVA 2010-860
Rum Creek Preparation Plant
WEVA 2008-1647
Rum Creek Preparation Plant
WEVA 2009-1160
Rum Creek Preparation Plant
WEVA 2009-121
Rum Creek Preparation Plant
WEVA 2009-1386
Rum Creek Preparation Plant
WEVA 2009-1661
Rum Creek Preparation Plant
WEVA 2009-672
Rum Creek Preparation Plant
WEVA 2009-690
Seng Creek Powellton
WEVA 2009-1113
Seng Creek Powellton
WEVA 2009-1589
Seng Creek Powellton
WEVA 2010-731
Shadrick 5 Block
WEVA 2009-1457
Shadrick 5 Block
WEVA 2009-1930
Sidney Coal Company, Inc.
N/A
Sidney Trucking
N/A
Slabcamp
WEVA 2009-1459
Slabcamp
WEVA 2009-1460
Slip Ridge Cedar Grove Mine
WEVA 2008-1093
Slip Ridge Cedar Grove Mine
WEVA 2008-1094
Slip Ridge Cedar Grove Mine
WEVA 2009-1048
Slip Ridge Cedar Grove Mine
WEVA 2009-1049
Slip Ridge Cedar Grove Mine
WEVA 2009-1318
Slip Ridge Cedar Grove Mine
WEVA 2009-1464
Slip Ridge Cedar Grove Mine
WEVA 2009-1797
Slip Ridge Cedar Grove Mine
WEVA 2009-1881
Slip Ridge Cedar Grove Mine
WEVA 2009-452
Slip Ridge Cedar Grove Mine
WEVA 2009-629
Slip Ridge Cedar Grove Mine
WEVA 2009-67
Slip Ridge Cedar Grove Mine
WEVA 2009-732
Slip Ridge Cedar Grove Mine
WEVA 2009-909
Slip Ridge Cedar Grove Mine
WEVA 2010-1030-D
Stockton Mine
WEVA 2009-1845
Superior Surface Mine
WEVA 2008-1431
Superior Surface Mine
WEVA 2008-1617
Superior Surface Mine
WEVA 2008-1773
Superior Surface Mine
WEVA 2008-1774
Superior Surface Mine
WEVA 2009-780
Superior Surface Mine
WEVA 2009-936
Superior Surface Mine
WEVA 2009-99
Taylor Fork Energy
KENT 2009-1034
Taylor Fork Energy
KENT 2009-111
Taylor Fork Energy
KENT 2009-1147
Taylor Fork Energy
KENT 2009-1267
Taylor Fork Energy
KENT 2009-1424
Taylor Fork Energy
KENT 2009-1500
Taylor Fork Energy
KENT 2009-685
Taylor Fork Energy
KENT 2009-902
Taylor Fork Energy
KENT 2010-1039
Taylor Fork Energy
KENT 2010-1171
Taylor Fork Energy
KENT 2010-1446
Taylor Fork Energy
KENT 2010-1535
Taylor Fork Energy
KENT 2010-180
Taylor Fork Energy
KENT 2010-314
Taylor Fork Energy
KENT 2010-448
Taylor Fork Energy
KENT 2010-52
Taylor Fork Energy
KENT 2010-53
Taylor Fork Energy
KENT 2010-554
Taylor Fork Energy
KENT 2010-772
Taylor Fork Energy
KENT 2010-915
Taylor Fork Energy
KENT 2010-1647-R
Tiller No 1
VA 2008-215
Tiller No 1
VA 2008-359
Tiller No 1
VA 2008-400
Tiller No 1
VA 2008-434-R & VA 2008-436-R
Tiller No 1
VA 2008-435-R & VA 2009-62
Tiller No 1
VA 2008-437-R & VA 2008-439-R
Tiller No 1
VA 2008-440/441
Tiller No 1
VA 2008-76
Tiller No 1
VA 2009-101
Tiller No 1
VA 2009-128
Tiller No 1
VA 2009-140
Tiller No 1
VA 2009-169
Tiller No 1
VA 2009-195
Tiller No 1
VA 2009-26
Tiller No 1
VA 2009-27
Tiller No 1
VA 2009-342
Tiller No 1
VA 2009-417
Tiller No 1
VA 2010-121
Tiller No 1
VA 2010-16
Tiller No 1
VA 2010-166
Tiller No 1
VA 2010-212
Tiller No 1
VA 2010-255/256
Tiller No 1
VA 2010-257
Tiller No 1
VA 2010-355
Tiller No 1
VA 2010-417
Tiller No 1
VA 2010-418
Tiller No 1
VA 2010-419
Tiller No 1
VA 2010-420
Tiller No 1
VA 2010-547
Tiller No 1
VA 2010-548
Tiller No 1
VA 2010-549
Tiller No 1
VA 2010-56
Tower Mountain
WEVA 2009-123
Tower Mountain
WEVA 2009-1808
Tower Mountain
WEVA 2009-832
Triumph Mine
KENT 2009-1288
Triumph Mine
KENT 2010-1046
Triumph Mine
KENT 2010-1255
Triumph Mine
KENT 2010-1413
Triumph Mine
KENT 2010-486
Triumph Mine
KENT 2010-487
Triumph Mine
KENT 2010-778
Triumph Mine
KENT 2010-926
Triumph Mine
N/A
Upper Big Branch Mine Raw Coal Facility
WEVA 2008-887
Upper Big Branch Mine-South
HOPE-CD-2010-17   District 4
Upper Big Branch Mine-South
N/A
Upper Big Branch Mine-South
N/A
Upper Big Branch Mine-South
WEVA 2007-460
Upper Big Branch Mine-South
WEVA 2007-470
Upper Big Branch Mine-South
WEVA 2007-576
Upper Big Branch Mine-South
WEVA 2007-608
Upper Big Branch Mine-South
WEVA 2007-608
Upper Big Branch Mine-South
WEVA 2007-608
Upper Big Branch Mine-South
WEVA 2007-672
Upper Big Branch Mine-South
WEVA 2007-767
Upper Big Branch Mine-South
WEVA 2008-1825
Upper Big Branch Mine-South
WEVA 2008-249
Upper Big Branch Mine-South
WEVA 2008-887
Upper Big Branch Mine-South
WEVA 2008-888
Upper Big Branch Mine-South
WEVA 2008-889
Upper Big Branch Mine-South
WEVA 2008-890
Upper Big Branch Mine-South
WEVA 2008-891
Upper Big Branch Mine-South
WEVA 2008-892
Upper Big Branch Mine-South
WEVA 2009-1129
Upper Big Branch Mine-South
WEVA 2009-1130
Upper Big Branch Mine-South
WEVA 2009-129
Upper Big Branch Mine-South
WEVA 2009-1375
Upper Big Branch Mine-South
WEVA 2009-1839
Upper Big Branch Mine-South
WEVA 2009-1840
Upper Big Branch Mine-South
WEVA 2009-1928
Upper Big Branch Mine-South
WEVA 2009-1929
Upper Big Branch Mine-South
WEVA 2009-281
Upper Big Branch Mine-South
WEVA 2009-282
Upper Big Branch Mine-South
WEVA 2009-283
Upper Big Branch Mine-South
WEVA 2009-370
Upper Big Branch Mine-South
WEVA 2009-831
Upper Big Branch Mine-South
WEVA 2010-1080-R; WEVA 2010-1249-R thru 2010-1279-R
Upper Big Branch Mine-South
WEVA 2010-1190-R
Upper Big Branch Mine-South
WEVA 2010-1213
Upper Big Branch Mine-South
WEVA 2010-195
Upper Big Branch Mine-South
WEVA 2010-206
Upper Big Branch Mine-South
WEVA 2010-207
Upper Big Branch Mine-South
WEVA 2010-318
Upper Big Branch Mine-South
WEVA 2010-319
Upper Big Branch Mine-South
WEVA 2010-535
Upper Big Branch Mine-South
WEVA 2010-626
Upper Big Branch Mine-South
WEVA 2010-64
Upper Big Branch Mine-South
WEVA 2010-65
Upper Big Branch Mine-South
WEVA 2010-728
Upper Big Branch Mine-South
WEVA 2010-729
Upper Big Branch Mine-South
WEVA 2010-869
Upper Big Branch Mine-South
WEVA 2010-902
Upper Big Branch Mine-South
WEVA 2010-903
Upper Big Branch Mine-South
WEVA 2010-941
Upper Big Branch Mine-South
WEVA 2010-978
Upper Big Branch Mine-South
WEVA 2010-979
Voyager #7
KENT 2009-1496
Voyager #7
KENT 2010-1012
Voyager #7
KENT 2010-1164
Voyager #7
KENT 2010-1257
Voyager #7
KENT 2010-1561
Voyager #7
KENT 2010-1562
Voyager #7
KENT 2010-170
Voyager #7
KENT 2010-200
Voyager #7
KENT 2010-311
Voyager #7
KENT 2010-427
Voyager #7
KENT 2010-530
Voyager #7
KENT 2010-60
Voyager #7
KENT 2010-734
Voyager #7
KENT 2010-906
West Cazy Surface Mine
WEVA 2008-848
West Cazy Surface Mine
WEVA 2009-267
White Buck No 2
WEVA 2008-1645
White Buck No 2
WEVA 2009-1908
White Cabin #7
KENT 2010-1256
White Cabin #7
KENT 2010-1560
White Cabin #7
KENT 2010-426
White Cabin #7
KENT 2010-533
White Cabin #7
KENT 2010-54
White Cabin #7
KENT 2010-733
White Queen
WEVA 2008-1466
White Queen
WEVA 2008-386
White Queen
WEVA 2009-1045
White Queen
WEVA 2009-1885
White Queen
WEVA 2009-626
White Queen
WEVA 2009-902
Winifrede #1 Mine
WEVA 2008-1651
Winifrede #1 Mine
WEVA 2008-79
   
   
N/A - Docket number has not yet been assigned

 
 

 EX-101.INS 8 mee-20100930.xml EX-101 INSTANCE DOCUMENT 0000037748 2008-12-31 0000037748 2009-01-01 2009-09-30 0000037748 2009-06-30 0000037748 2009-09-30 0000037748 2009-12-31 0000037748 2009-07-01 2009-09-30 0000037748 2010-01-01 2010-09-30 0000037748 2010-07-01 2010-09-30 0000037748 2010-09-30 iso4217:USD xbrli:shares iso4217:USD xbrli:shares <div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">(1)</font><font style="LETTER-SPACING: 9pt; COLOR: black">&#160;&#160; </font><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Significant Accounting Policies</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Basis of Presentation</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times Ne w Roman; FONT-SIZE: 10pt">The Condensed Consolidated Financial Statements do not include footnotes and certain financial information normally presented annually under accounting principles generally accepted in the United States ("GAAP") and, therefore, should be read in conjunction with the Annual Report on Form 10-K of Massey Energy Company ("we," "our," "us" or the "Company") for the year ended December 31, 2009.&#160;&#160;Accounting measurements at interim dates inherently involve greater reliance on estimates than at year-end.&#160;&#160;The results of operations for the quarterly period ended September 30, 2010 are not necessarily indicative of results that can be expected for the fiscal year ending December 31, 2010.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">The Condensed Consolidated Financial Statements included herein are unaudited; however, the financial statements contain all adjustments (consisting of normal recurring accruals), which, in our opinion, are necessary to present fairly our consolidated financial position at September 30, 2010, our consolidated results of operations for the three and nine months ended September 30, 2010 and 2009, and cash flows for the nine months ended September 30, 2010 and 2009, in conformity with GAAP.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">The Condensed Consolidated Financial Statements include our accounts and the accounts of our wholly-owned and majority-owned direct and indirect subsidiaries.&#160;&#160;Significant intercompany transactions and a ccounts are eliminated in consolidation.&#160;&#160;We have no independent assets or operations.&#160;&#160;We do not have a controlling interest in any separate independent operations.&#160;&#160;Investments in business entities in which we do not have control, but have the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">All of our direct and substantially all of our indirect operating subsidiaries, each such subsidiary being indirectly 100% owned by us, fully and unconditionally, jointly and severally, guarantee our obligations under the 6.875% senior notes due 2013 ("6.875% Notes"), the 3.25% convertible senior notes du e 2015 ("3.25% Notes") and the 2.25% convertible senior notes due 2024 ("2.25% Notes").&#160;&#160;The subsidiaries not providing a guarantee of the 6.875% Notes, the 3.25% Notes and the 2.25% Notes are minor (as defined under Securities and Exchange Commission ("SEC") Rule 3-10(h)(6) of Regulation S-X).&#160;&#160;See Note 7 to the Notes to Condensed Consolidated Financial Statements for a more complete discussion of debt.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We have evaluated subsequent events through the date the Condensed Consolidated Financial Statements were issued.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-R IGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Goodwill</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Goodwill represents the excess of the purchase price over the fair value of the net identifiable tangible and intangible assets of acquired companies.&#160;&#160;Goodwill is not amortized; instead, it is tested for impairment annually or more frequently if indicators of impairment exist.&#160;&#160;As a result of the acquisition of Cumberland Resources Corporation and certain affiliated companies ("Cumberland") during the second quarter of 2010, we recorded Goodwill in our Condensed Consolidated Balance Sheet.&#160;&#160;As purchase accounting is considered prel iminary as of the date the Condensed Consolidated Financial Statements were issued, the goodwill amount recorded may be adjusted.&#160;&#160;We have not allocated goodwill to the appropriate reporting unit(s) for the purpose of impairment testing as of the date the Condensed Consolidated Financial Statements were issued. See Note 2 to the Notes to Condensed Consolidated Financial Statements for more information.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Asset Impairment and Disposal of Long-Lived Assets</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Long-lived assets, such as property, equipment, mine development costs, owned and leased mineral rights longwall panel costs and purchased intangibles subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to its </font></div><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160;6 </font></div><div style="TEXT-ALIGN: cen ter; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">estimated fair value.&#160;&#160;The fair value is determined using the estimated undiscounted cash flows expected to be generated by the assets along with, where appropriate, market inputs.&#160;&#160;The determination of fair value requires the use of significant judgment and estimates about assumptions that management believes are appropriate in the circumstances although it is reasonably possible that actual performance will differ from these assumptions.&#160;&#160;If the carrying amount of an asset exceeds its estimated fair value, an impairment charge is recognized equal to the amount by which the carrying amount of the as set exceeds the estimated fair value of the asset.&#160;&#160;See Note 5 to the Notes to Condensed Consolidated Financial Statements for more information.</font></div></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Insurance Recoveries</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Insurance recoveries that are deemed to be probable and reasonably estimable are recognized to the extent of the related loss.&#160;&#160;Insurance recoveries that result in gains are recognized only when realized by sett lement with the insurers.&#160;&#160;The evaluation of insurance recoveries requires estimates and judgments about future results that affect reported amounts and certain disclosures. Actual results could differ from those estimates.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt"><a id="lastkeyword" name="lastkeyword"><!--EFPlaceholder--></a>Recent Accounting Pronouncements</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">In January 2010, the Financial Accounting Standards Board (the "FASB" ) issued an accounting standard update, amending disclosure requirements related to Fair Value Measurements and Disclosures, as follows:</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div><table style="FONT-FAMILY: times new roman; FONT-SIZE: 10pt" cellspacing="0" cellpadding="0" width="100%"><tr valign="top"><td style="WIDTH: 63pt" align="right"><div><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">1.&#160;&#160;</font></div></td><td><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Significant transfers between Level 1 and 2 shall be disclosed separately, including the reasons for the transfers; and</font></div></td></tr></table></div><div><table style="FONT-FAMILY: times new roman; FONT-SIZE: 1 0pt" cellspacing="0" cellpadding="0" width="100%"><tr valign="top"><td style="WIDTH: 63pt" align="right"><div><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">2.&#160;&#160;</font></div></td><td><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Information about purchases, sales, issuances and settlements shall be disclosed separately in the reconciliation of activity in Level 3 fair value measurements.</font></div></td></tr></table></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">This accounting standard update is effective for interim and annual re porting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances and settlements in the reconciliation of activity in Level 3 fair value measurements, which are effective for interim and annual reporting periods beginning after December 15, 2010. 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Plaintiffs seek injunctive relief and compensatory and punitive damages.&#160;&#160;The Supreme Court of Appeals of West Virginia ("WV Supreme Court") referred the consolidated lawsuits, and similar lawsuits against other coal and transportation companies not involving our subsidiaries, to the Circuit Court of Lincoln County, West Virginia ("Circuit Court"), to be handled by a mass litigation panel judge. Plaintiffs filed motions requesting class certification. On June 7, 2007, plaintiffs voluntarily dismissed their public nuisance claims seeking monetary damages for road and bridge repairs.&#160;&#160;Plaintiffs also agreed to an order limiting any damages for nuisance to two years prior to the filing of any suit.&#160;&#160;A motion to dismiss any remaining public nuisance claims was resisted by plaintiffs and argued at hearings on December 14, 2007 and June 25, 2008.&#160;&#160;No rulings on these matters have been made.&#160;&#160;Defendants filed a motion requesting that the mass litigation panel judge recommend to the WV Supreme Court that the cases be sent back to the circuit courts of origin for resolution.&#160;&#160;That motion was verbally denied as to those cases in which our sub sidiaries are defendants, and a class certification hearing was held on October 21, 2009.&#160;&#160;To date, no decision has been rendered by the Circuit Court on the class certification issues.&#160;&#160;No date has been set for trial.&#160;&#160;We believe we have insurance coverage applicable to these items and that they will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Well Water Suits</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY : inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Since September 2004, approximately 738 plaintiffs have filed approximately 400 suits against us and our subsidiary, Rawl Sales &amp; Processing Co., in the Circuit Court of Mingo County, West Virginia ("Mingo Court"), for alleged property damage and personal injuries arising out of slurry injection and impoundment practices allegedly contaminating plaintiffs' water wells. Plaintiffs seek injunctive relief and compensatory damages in excess of $170 million and unquantified punitive damages.&#160;&#160;Specifically, plaintiffs are claiming that defendants' activities during the period of 1978 through 1987 rendered their property valueless and request monetary damages to pay, inter alia, the value of their property and future water bills.&#160;&#160;In addition, many plaintiffs are also claiming that their exposure to the contaminated well water caused neurological injury or physical injury, including cancers, kidney problems and g all stones.&#160;&#160;Finally, all plaintiffs claimed entitlement to medical monitoring for the next 30 years and have requested unliquidated compensatory damages for pain and suffering, annoyance and inconvenience and legal fees.&#160;&#160;On April 30, 2009, the Mingo Court held a mandatory settlement conference. At that settlement conference, all plaintiffs agreed to settle and dismiss their medical monitoring claims.&#160;&#160;Additionally, 180 plaintiffs agreed to settle all of their remaining claims and be dismissed from the case.&#160;&#160;All settlements to date will be funded by insurance proceeds.&#160;&#160;Plaintiffs are challenging the medical monitoring settlement.&#160;&#160;A motion to enforce the medical monitoring settlement has been filed.&#160;&#160;No ruling has been made.&#160;&#160;There are currently 585 plaintiffs remaining.&#160;&#160;Mediation of all pending suits is scheduled to begin in November, 2010 in C harleston, West Virginia.&#160;&#160;A trial date has been set for August 2011, if the mediation fails to lead to a settlement.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Beginning in December 2008, we and certain of our subsidiaries along with several other companies were sued in numerous actions in Boone County, West Virginia involving approximately 370 plaintiffs alleging well water contamination resulting from coal mining operations.&#160;&#160;The claims mirror those made above in the separate action before the Mingo Court.&#160;&#160;The separate civil actions have been consolidated for discovery purposes with trial for 267 plaintiffs scheduled for October 25, 2011.&#160;&#160;No trial date is set for the remaining approximately 102 plaintiffs.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We do not believe there was any contamination caused by our activities or that plaintiffs suffered any damage and, therefore, we do not believe we have a probable loss related to these matters.&#160;&#160;We plan to vigorously contest these claims.&#160;&#160;We believe that we have insurance coverage applicable to these matters and have initiated litigation against our insurers to establish that coverage.&#160;&#160;At this time, we believe that the litigation by the plaintiffs will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.</font><br /></div><br /><div style="TEXT-INDENT: 0pt; WIDTH: 100%; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">20&#160; </font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div></div><br /><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Surface Mining F ills</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Since September 2005, three environmental groups sued the United States Army Corps of Engineers ("Corps") in the United States District Court for the Southern District of West Virginia (the "District Court"), asserting the Corps unlawfully issued permits to four of our surface mines to construct mining fills. The suit alleges the Corps failed to comply with the requirements of both Section 404 of the Clean Water Act and the National Environmental Policy Act, including preparing environmental impact statements for individual permits. We intervened in the suit to protect our interests. On March 23, 2007, the District Court rescinded four of our subsidiaries' permits, resulting in the temporary suspension of mining at thes e surface mines. We appealed that ruling to the United States Court of Appeals for the Fourth Circuit (the "Fourth Circuit Court"). On April 17, 2007, the District Court partially stayed its ruling, permitting mining to resume in certain fills that were already under construction. On June 14, 2007, the District Court issued an additional ruling, finding the Corps improperly approved placement of sediment ponds in streams below fills on the four permits in question.&#160;&#160;The District Court subsequently modified its ruling to allow these ponds to remain in place, as the ponds and fills have already been constructed.&#160;&#160;The District Court's ruling could impact the issuance of permits for the placement of sediment ponds for future operations. If the permits for the fills or sediment ponds are ultimately held to be unlawfully issued, production could be affected at these surface mines, and the process of obtaining new Corps permits for all surface mines could become more difficult. W e appealed both rulings to the Fourth Circuit Court.&#160;&#160;On February 13, 2009, the Fourth Circuit Court reversed the prior rulings of the District Court and remanded the matter for further proceedings. On March 30, 2009, the plaintiffs requested that the Fourth Circuit Court reconsider the case.&#160;&#160;The request was denied on May 20, 2009. On August 26, 2009, the plaintiffs filed their request with the United States Supreme Court to review the Fourth Circuit Court's decision.&#160;&#160;Our subsidiaries' response was due on August 5, 2010. However, on August 3, 2010, the plaintiffs moved to withdraw their petition in the wake of a new policy adopted by the Corps and the Environmental Protection Agency on July 30, 2010 for assessing "stream ecosystem structure and function" for Appalachian surface coal mining. The motion to withdraw the petition for certiorari was granted, thereby finalizing the Fourth Circuit Court's decision.</font></div><div style="TEXT-I NDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Customer Disputes</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We have customers who claim they did not receive, or did not timely receive, all of the coal required to be shipped to them during 2008 ("unshipped tons"). In such cases, it is typical for a customer and coal producer to agree upon a schedule for shipping unshipped tons in subsequent years.&#160;&#160;A few of our customers, however, filed claims for cover damages, which damages are equal to the difference between the contract price of the coal that was not delivered and the market price of replacement coal or comparable quality coal. We resolved a number of these claims in 2009 and 2010, while discussions with other customers remain ongoing.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We believe we have strong defenses to the remaining claims for cover damages.&#160;&#160;In many cases, there was untimely or insufficient delivery of railcars by the rail carrier or the customer.&#160;&#160;In other cases, factors beyond our control caused production or shipment problems.&#160;&#160;Additionally, we believe that certain customers previously agreed to accept unshipped tons in subsequent years.&#160;&#160;We believe that all of these factors, and other factors, provide defen ses to claims or potential claims for unshipped tons.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Separately, we are currently in litigation with one customer regarding whether or not binding contracts for the sale of coal were reached.&#160;&#160;We maintain that this customer improperly terminated a signed, higher-priced contract; the customer argues that it was only required to purchase coal under a purported agreement reached by email. On February 12, 2010, we received a decision from an arbitration panel awarding this customer $10.5 million on the grounds that the purported agreement by email was valid and that the higher-priced contract was invalid.&#160;&#160;We believed that the arbitration panel's decision as to the validity of the higher-pric ed contract was beyond the panel's jurisdiction of the award, which amounts to $8.2 million, and challenged that decision in federal court.&#160;&#160;On June 2, 2010, the federal court rejected our challenge.&#160;&#160;We are appealing this matter to the United States Court of Appeals for the Fourth Circuit Court.&#160;&#160;While we will vigorously pursue this appeal, we have accrued the remainder of the judgment in Other current liabilities at September 30, 2010.&#160;&#160;We have paid $2.3 million for the award relating to the panels' decision that the agreement by email was valid, but have not yet paid the portion of the award under appeal.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We believe that we have strong defenses to the other claims and potential claims and further feel that many or all of these claims may be resolved without trial. We have recorded an accrual for our best estimate of probable</font></div><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">21&#160; </font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div><font style="DISPLAY: i nline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">losses related to these matters. While we believe that all of these matters discussed above will be resolved without a material adverse impact on our cash flows, results of operations or financial condition, it is reasonably possible that our judgments regarding some or all of these matters could change in the near term. We believe the aggregate exposure related to these claims in excess of our accrual is up to $4 million of charges that would affect our future operating results and financial position.</font></div></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Spartan Unfair Labor Practice Matter &amp; Related Age Discrimination Class Action</font></div><div style="TEXT-INDENT : 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">In 2005, the United Mine Workers of America ("UMWA") filed an unfair labor practice charge with the National Labor Relations Board ("NLRB") alleging that one of our subsidiaries, Spartan Mining Company ("Spartan"), discriminated on the basis of anti-union animus in its employment offers.&#160;&#160;The NLRB issued a complaint and an NLRB Administrative Law Judge ("ALJ") issued a recommended decision making detailed findings that Spartan committed a number of unfair labor practice violations and awarding, among other relief, back pay damages to union discriminatees.&#160;&#160;On September 30, 2009, the NLRB upheld the ALJ's recommended decision.&#160;&#160;Spartan has appealed the NLRB's decision to the Fourth Circuit Court. We have no insurance cove rage applicable to this unfair labor practice matter; however, its resolution is not expected to have a material impact on our cash flows, results of operations or financial condition.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Upper Big Branch Mine</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">On April 5, 2010, an accident occurred at the Upper Big Branch mine of our Performance resource group, tragically resulting in the deaths of 29 miners and seriously injuring two others.&#160;&#160;The Federal M ine Safety and Health Administration ("MSHA") and the State of West Virginia have undertaken a joint investigation into the cause of the UBB tragedy.&#160;&#160;We also have commenced our own investigation.&#160;&#160;We believe these investigations will continue for the foreseeable future, and we cannot provide any assurance as to their outcome, including whether we become subject to possible civil penalties or enforcement actions.&#160;&#160;In order to accommodate these investigations, the UBB mine will be closed for an extended period of time, the length of which we cannot predict at this time.&#160;&#160;It is also possible that we may decide or be required by regulators to permanently close the UBB mine.&#160;&#160;We self-insure our underground mining equipment, including longwalls, at or near the UBB mine.&#160;&#160;We do not currently carry business interruption insurance for the UBB mine.&#160;&#160;We have third-party general liability insur ance coverage that applies to litigation risk, which coverage we believe applies to litigation stemming from the UBB tragedy.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">While updated analyses will continue in future quarters, we have recorded our best estimate of probable losses related to this matter.&#160;&#160;The most significant components of these losses related to: the benefits being provided to the families of the fallen miners (see Note 10 to the Notes to Condensed Consolidated Financial Statements for more information about the significant benefits provided), costs associated with the rescue and recovery efforts, possible legal and other contingencies, and asset impairment charges (see Note 5 to the Notes to Condensed Consolidated Financial Statemen ts for more information).&#160;&#160;We have recorded a $78 million liability in Other current liabilities at September 30, 2010, which represents our best estimate of the probable loss related to potential future litigation settlements associated with the UBB tragedy.&#160;&#160;Two of the families have filed wrongful death suits against us, while&#160;seven families have signed agreements to settle their claims (three of which have been finalized after receiving the required judicial approval).&#160;&#160;Insurance recoveries related to our general liability insurance policy that are deemed probable and that are reasonably estimable have been recognized in the Condensed Consolidated Statements of Income to the extent of the related losses, less applicable deductibles.&#160;&#160;Such recognized recoveries for litigation settlements associated with the UBB tragedy totaled $78 million and are included in Trade and other accounts receivable at September 30, 2010.</font&g t;</div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Given the uncertainty of the outcome of current investigations, including whether we become subject to possible civil penalties or enforcement actions, it is possible that the total costs incurred related to this tragedy could exceed our current estimates.&#160;&#160;As of September 30, 2010, we believe that the reasonably possible aggregate loss related to these claims in excess of amounts currently recorded cannot be estimated.&#160;&#160;It is possible, however, that the ultimate liabilities in the future with respect to these claims, in the aggregate, may be material.&#160;&#160;We will continue to review the amount of any necessary accruals, potential asset impairments, or other related expenses and record the charges in the period in which the determination is made and an adjustment is required.</font><br /></div><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; 22</font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN- RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Clean Water Act Citizens' Suits</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">&#160;The Sierra Club and others have filed two citizens' suits against several of our subsidiaries in federal court in the Southern District of West Virginia alleging violations of the terms of our water discharge permits. One of the cases is limited to allegations that two of our subsidiaries, Independence Coal Company and Jacks Branch Coal Company, are violating limits on the allowable concentrations of selenium in their discharges of storm water from several surface mines. The other action is limited to claims that several of our subsidiaries are violati ng discharge limits on substances other than selenium, such as aluminum. The plaintiffs in these cases seek both a civil penalty and injunctive relief.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">In the non-selenium case, we have argued that the alleged violations are contemplated by an existing consent decree with the United States government and should not be the subject of a new lawsuit.&#160;&#160;In the selenium case, we have argued that the limits on selenium concentrations in our discharges have been stayed by an order of the West Virginia Environmental Quality Board and therefore cannot be the subject of a Clean Water Act case until after those limits become effective. The plaintiffs have nonetheless filed a motion for summary judgment in the selenium case, arguing that we are in violation of our permit limits despite the stays.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Other Legal Proceedings</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We are parties to a number of other legal proceedings, incident to our normal business activities.&#160;&#160;These include, for example, contract disputes, personal injury claims, property damage claims, environmental issues, and employment and safety matters.<font style="DISPLAY: inline; FONT-WEIGHT: bold"&g t;&#160;</font>While we cannot predict the outcome of any of these proceedings, based on our current estimates we do not believe that any liability arising from these matters individually or in the aggregate should have a material adverse impact upon our consolidated cash flows, results of operations or financial condition.&#160;&#160;It is possible, however, that the ultimate liabilities in the future with respect to these lawsuits and claims, in the aggregate, may be materially adverse to our cash flows, results of operations or financial condition.</font></div> 1184000 2175000 -46219000 10122000 1891036000 1256283000 0 0 33134000 0 998000 1303000 17356000 15283000 3041000 15704000 268062000 232110000 603456000 538058000 76839000 66105000 273962000 204524000 12283000 38936000 68873000 72504000 -466707000 0 -5810000 0 71014000 63590000 1220363000 1314565000 289527000 121577000 <div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">(13)&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;Derivative Instruments</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Upon entering into each coal sales and coal purchase contract, we evaluate each of our contracts to determine if they qualify for the normal purchase normal sale ("NPNS") exception prescribed by current accounting guidance.&#160;&#160;We use coal purchase contracts to supplement our produced and processed co al in order to provide coal to meet customer requirements under sales contracts.&#160;&#160;We are exposed to certain risks related to coal price volatility.&#160;&#160;The purchases and sales contracts we enter into allow us to mitigate a portion of the underlying risk associated with coal price volatility.&#160;&#160;The majority of our contracts qualify for the NPNS exception and therefore are not accounted for at fair value.&#160;&#160;For those contracts that do not qualify for the NPNS exception at inception or lose their designation at some point during the duration of the contract, the contracts are required to be accounted for as derivative instruments and must be recognized as assets or liabilities and measured at fair value.&#160;&#160;Those contracts that do not qualify for the NPNS exception have not been designated as cash flow or fair value hedges and, accordingly, the net change in fair value is recorded in current period earnings.&#160;&#160;Ou r coal sales and coal purchase contracts that do not qualify for the NPNS exception as prescribed by current accounting guidance are offset on a counterparty-by-counterparty basis for derivative instruments executed with the same counterparty under a master netting arrangement.</font></div><br /><div style="TEXT-INDENT: 0pt; WIDTH: 100%; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISP LAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div></div><br /><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Tons outstanding under coal purchase and coal sales contracts that do not qualify for the NPNS exception are as follows:</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; 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FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We paid benefits to participants of the nonqualified supplemental benefit pension plan of $0.01 million and $0.02 million for the three months ended September 30, 2010 and 2009, respectively, and $0.06 million and $0.05 million for the nine months ended September 30, 2010 and 2009, respectively.</font></div> (8)&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;Pension ExpenseNet periodic pension expense for both our qualified defined benefit pension false false false us-types:textBlockItemType textblock Description containing the entire pension benefits disclosure as a single block of text. 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Plaintiffs seek injunctive relief and compensatory and punitive damages.&#160;&#160;The Supreme Court of Appeals of West Virginia ("WV Supreme Court") referred the consolidated lawsuits, and similar lawsuits against other coal and transportation companies not involving our subs idiaries, to the Circuit Court of Lincoln County, West Virginia ("Circuit Court"), to be handled by a mass litigation panel judge. Plaintiffs filed motions requesting class certification. On June 7, 2007, plaintiffs voluntarily dismissed their public nuisance claims seeking monetary damages for road and bridge repairs.&#160;&#160;Plaintiffs also agreed to an order limiting any damages for nuisance to two years prior to the filing of any suit.&#160;&#160;A motion to dismiss any remaining public nuisance claims was resisted by plaintiffs and argued at hearings on December 14, 2007 and June 25, 2008.&#160;&#160;No rulings on these matters have been made.&#160;&#160;Defendants filed a motion requesting that the mass litigation panel judge recommend to the WV Supreme Court that the cases be sent back to the circuit courts of origin for resolution.&#160;&#160;That motion was verbally denied as to those cases in which our subsidiaries are defendants, and a class certification hearing was held on October 21, 2009.&#160;&#160;To date, no decision has been rendered by the Circuit Court on the class certification issues.&#160;&#160;No date has been set for trial.&#160;&#160;We believe we have insurance coverage applicable to these items and that they will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Well Water Suits</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Since September 2004, approximately 738 plaintiffs have filed approximately 400 suits against us and our subsidiary, Rawl Sales &amp; Processing Co., in the Circuit Court of Mingo County, West Virginia ("Mingo Court"), for alleged property damage and personal injuries arising out of slurry injection and impoundment practices allegedly contaminating plaintiffs' water wells. Plaintiffs seek injunctive relief and compensatory damages in excess of $170 million and unquantified punitive damages.&#160;&#160;Specifically, plaintiffs are claiming that defendants' activities during the period of 1978 through 1987 rendered their property valueless and request monetary damages to pay, inter alia, the value of their property and future water bills.&#160;&#160;In addition, many plaintiffs are also claiming that their exposure to the contaminated well water caused neurological injury or physical injury, including cancers, kidney problems and gall stones.&#160;&#160;Finally, all plainti ffs claimed entitlement to medical monitoring for the next 30 years and have requested unliquidated compensatory damages for pain and suffering, annoyance and inconvenience and legal fees.&#160;&#160;On April 30, 2009, the Mingo Court held a mandatory settlement conference. At that settlement conference, all plaintiffs agreed to settle and dismiss their medical monitoring claims.&#160;&#160;Additionally, 180 plaintiffs agreed to settle all of their remaining claims and be dismissed from the case.&#160;&#160;All settlements to date will be funded by insurance proceeds.&#160;&#160;Plaintiffs are challenging the medical monitoring settlement.&#160;&#160;A motion to enforce the medical monitoring settlement has been filed.&#160;&#160;No ruling has been made.&#160;&#160;There are currently 585 plaintiffs remaining.&#160;&#160;Mediation of all pending suits is scheduled to begin in November, 2010 in Charleston, West Virginia.&#160;&#160;A tria l date has been set for August 2011, if the mediation fails to lead to a settlement.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Beginning in December 2008, we and certain of our subsidiaries along with several other companies were sued in numerous actions in Boone County, West Virginia involving approximately 370 plaintiffs alleging well water contamination resulting from coal mining operations.&#160;&#160;The claims mirror those made above in the separate action before the Mingo Court.&#160;&#160;The separate civil actions have been consolidated for discovery purposes with trial for 267 plaintiffs scheduled for October 25, 2011.&#160;&#160;No trial date is set for the remaining approximately 102 plaintiffs.</font></div><div sty le="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We do not believe there was any contamination caused by our activities or that plaintiffs suffered any damage and, therefore, we do not believe we have a probable loss related to these matters.&#160;&#160;We plan to vigorously contest these claims.&#160;&#160;We believe that we have insurance coverage applicable to these matters and have initiated litigation against our insurers to establish that coverage.&#160;&#160;At this time, we believe that the litigation by the plaintiffs will be resolved without a material adverse impact on our cash flows, results of operations or financial condition.</font><br /></div><br /><div style="TEXT-INDENT: 0pt; WIDTH: 100%; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div> <div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">20&#160; </font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div></div><br /><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Surface Mining Fills</font></div><div style="TEXT-IN DENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Since September 2005, three environmental groups sued the United States Army Corps of Engineers ("Corps") in the United States District Court for the Southern District of West Virginia (the "District Court"), asserting the Corps unlawfully issued permits to four of our surface mines to construct mining fills. The suit alleges the Corps failed to comply with the requirements of both Section 404 of the Clean Water Act and the National Environmental Policy Act, including preparing environmental impact statements for individual permits. We intervened in the suit to protect our interests. On March 23, 2007, the District Court rescinded four of our subsidiaries' permits, resulting in the temporary suspension of mining at these surface mines. We appealed that ruling to the Uni ted States Court of Appeals for the Fourth Circuit (the "Fourth Circuit Court"). On April 17, 2007, the District Court partially stayed its ruling, permitting mining to resume in certain fills that were already under construction. On June 14, 2007, the District Court issued an additional ruling, finding the Corps improperly approved placement of sediment ponds in streams below fills on the four permits in question.&#160;&#160;The District Court subsequently modified its ruling to allow these ponds to remain in place, as the ponds and fills have already been constructed.&#160;&#160;The District Court's ruling could impact the issuance of permits for the placement of sediment ponds for future operations. If the permits for the fills or sediment ponds are ultimately held to be unlawfully issued, production could be affected at these surface mines, and the process of obtaining new Corps permits for all surface mines could become more difficult. We appealed both rulings to the Fourth Circuit Court .&#160;&#160;On February 13, 2009, the Fourth Circuit Court reversed the prior rulings of the District Court and remanded the matter for further proceedings. On March 30, 2009, the plaintiffs requested that the Fourth Circuit Court reconsider the case.&#160;&#160;The request was denied on May 20, 2009. On August 26, 2009, the plaintiffs filed their request with the United States Supreme Court to review the Fourth Circuit Court's decision.&#160;&#160;Our subsidiaries' response was due on August 5, 2010. However, on August 3, 2010, the plaintiffs moved to withdraw their petition in the wake of a new policy adopted by the Corps and the Environmental Protection Agency on July 30, 2010 for assessing "stream ecosystem structure and function" for Appalachian surface coal mining. The motion to withdraw the petition for certiorari was granted, thereby finalizing the Fourth Circuit Court's decision.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div ><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Customer Disputes</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We have customers who claim they did not receive, or did not timely receive, all of the coal required to be shipped to them during 2008 ("unshipped tons"). In such cases, it is typical for a customer and coal producer to agree upon a schedule for shipping unshipped tons in subsequent years.&#160;&#160;A few of our customers, however, filed claims for cover damages, which damages are equal to the difference between the contract price of the coal that was not delivered and the market price of replacement coal or comparable quality coal. We resolved a number of these claims in 2009 and 2010, while discussions with other customers remain ongoing.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We believe we have strong defenses to the remaining claims for cover damages.&#160;&#160;In many cases, there was untimely or insufficient delivery of railcars by the rail carrier or the customer.&#160;&#160;In other cases, factors beyond our control caused production or shipment problems.&#160;&#160;Additionally, we believe that certain customers previously agreed to accept unshipped tons in subsequent years.&#160;&#160;We believe that all of these factors, and other factors, provide defenses to claims or potential claims for unshipped ton s.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Separately, we are currently in litigation with one customer regarding whether or not binding contracts for the sale of coal were reached.&#160;&#160;We maintain that this customer improperly terminated a signed, higher-priced contract; the customer argues that it was only required to purchase coal under a purported agreement reached by email. On February 12, 2010, we received a decision from an arbitration panel awarding this customer $10.5 million on the grounds that the purported agreement by email was valid and that the higher-priced contract was invalid.&#160;&#160;We believed that the arbitration panel's decision as to the validity of the higher-priced contract was beyond the panel's jurisdiction of the award, which amounts to $8.2 million, and challenged that decision in federal court.&#160;&#160;On June 2, 2010, the federal court rejected our challenge.&#160;&#160;We are appealing this matter to the United States Court of Appeals for the Fourth Circuit Court.&#160;&#160;While we will vigorously pursue this appeal, we have accrued the remainder of the judgment in Other current liabilities at September 30, 2010.&#160;&#160;We have paid $2.3 million for the award relating to the panels' decision that the agreement by email was valid, but have not yet paid the portion of the award under appeal.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We believe that we have strong defenses to the other claims and potential claims and further feel that many or all of these claims may be resolved without trial. We have recorded an accrual for our best estimate of probable</font></div><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">21&#160; </font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10p t">losses related to these matters. While we believe that all of these matters discussed above will be resolved without a material adverse impact on our cash flows, results of operations or financial condition, it is reasonably possible that our judgments regarding some or all of these matters could change in the near term. We believe the aggregate exposure related to these claims in excess of our accrual is up to $4 million of charges that would affect our future operating results and financial position.</font></div></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Spartan Unfair Labor Practice Matter &amp; Related Age Discrimination Class Action</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div>& lt;div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">In 2005, the United Mine Workers of America ("UMWA") filed an unfair labor practice charge with the National Labor Relations Board ("NLRB") alleging that one of our subsidiaries, Spartan Mining Company ("Spartan"), discriminated on the basis of anti-union animus in its employment offers.&#160;&#160;The NLRB issued a complaint and an NLRB Administrative Law Judge ("ALJ") issued a recommended decision making detailed findings that Spartan committed a number of unfair labor practice violations and awarding, among other relief, back pay damages to union discriminatees.&#160;&#160;On September 30, 2009, the NLRB upheld the ALJ's recommended decision.&#160;&#160;Spartan has appealed the NLRB's decision to the Fourth Circuit Court. We have no insurance coverage applicable to this unfair labor practice matte r; however, its resolution is not expected to have a material impact on our cash flows, results of operations or financial condition.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Upper Big Branch Mine</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">On April 5, 2010, an accident occurred at the Upper Big Branch mine of our Performance resource group, tragically resulting in the deaths of 29 miners and seriously injuring two others.&#160;&#160;The Federal Mine Safety and Health Administration ("MSHA") and t he State of West Virginia have undertaken a joint investigation into the cause of the UBB tragedy.&#160;&#160;We also have commenced our own investigation.&#160;&#160;We believe these investigations will continue for the foreseeable future, and we cannot provide any assurance as to their outcome, including whether we become subject to possible civil penalties or enforcement actions.&#160;&#160;In order to accommodate these investigations, the UBB mine will be closed for an extended period of time, the length of which we cannot predict at this time.&#160;&#160;It is also possible that we may decide or be required by regulators to permanently close the UBB mine.&#160;&#160;We self-insure our underground mining equipment, including longwalls, at or near the UBB mine.&#160;&#160;We do not currently carry business interruption insurance for the UBB mine.&#160;&#160;We have third-party general liability insurance coverage that applies to litigation risk, whic h coverage we believe applies to litigation stemming from the UBB tragedy.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">While updated analyses will continue in future quarters, we have recorded our best estimate of probable losses related to this matter.&#160;&#160;The most significant components of these losses related to: the benefits being provided to the families of the fallen miners (see Note 10 to the Notes to Condensed Consolidated Financial Statements for more information about the significant benefits provided), costs associated with the rescue and recovery efforts, possible legal and other contingencies, and asset impairment charges (see Note 5 to the Notes to Condensed Consolidated Financial Statements for more information).&#160;&#160;We hav e recorded a $78 million liability in Other current liabilities at September 30, 2010, which represents our best estimate of the probable loss related to potential future litigation settlements associated with the UBB tragedy.&#160;&#160;Two of the families have filed wrongful death suits against us, while&#160;seven families have signed agreements to settle their claims (three of which have been finalized after receiving the required judicial approval).&#160;&#160;Insurance recoveries related to our general liability insurance policy that are deemed probable and that are reasonably estimable have been recognized in the Condensed Consolidated Statements of Income to the extent of the related losses, less applicable deductibles.&#160;&#160;Such recognized recoveries for litigation settlements associated with the UBB tragedy totaled $78 million and are included in Trade and other accounts receivable at September 30, 2010.</font></div><div style="TEXT-INDENT: 0pt; DISP LAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Given the uncertainty of the outcome of current investigations, including whether we become subject to possible civil penalties or enforcement actions, it is possible that the total costs incurred related to this tragedy could exceed our current estimates.&#160;&#160;As of September 30, 2010, we believe that the reasonably possible aggregate loss related to these claims in excess of amounts currently recorded cannot be estimated.&#160;&#160;It is possible, however, that the ultimate liabilities in the future with respect to these claims, in the aggregate, may be material.&#160;&#160;We will continue to review the amount of any necessary accruals, potential asset impairments, or other related expenses and record the charges in the period in which the determinati on is made and an adjustment is required.</font><br /></div><div style="TEXT-INDENT: 0pt; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt"><div><div style="WIDTH: 100%" align="left"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div><div style="PAGE-BREAK-AFTER: always; WIDTH: 100%"><div style="TEXT-ALIGN: center; WIDTH: 100%"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; 22</font></div><div style="TEXT-ALIGN: center; WIDTH: 100%"><hr style="COLOR: black" size="2" noshade="noshade" /></div></div><div><div style="WIDTH: 100%" align="right"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 8pt">&#160; </font></div></div></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT - -STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Clean Water Act Citizens' Suits</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">&#160;The Sierra Club and others have filed two citizens' suits against several of our subsidiaries in federal court in the Southern District of West Virginia alleging violations of the terms of our water discharge permits. One of the cases is limited to allegations that two of our subsidiaries, Independence Coal Company and Jacks Branch Coal Company, are violating limits on the allowable concentrations of selenium in their discharges of storm water from several surface mines. The other action is limited to claims that several of our subsidiaries are violating discharge limits on substances other than seleni um, such as aluminum. The plaintiffs in these cases seek both a civil penalty and injunctive relief.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">In the non-selenium case, we have argued that the alleged violations are contemplated by an existing consent decree with the United States government and should not be the subject of a new lawsuit.&#160;&#160;In the selenium case, we have argued that the limits on selenium concentrations in our discharges have been stayed by an order of the West Virginia Environmental Quality Board and therefore cannot be the subject of a Clean Water Act case until after those limits become effective. The plaintiffs have nonetheless filed a motion for summary judgment in the selenium case, arguing that we are in violation of our permi t limits despite the stays.</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 0pt; DISPLAY: block; MARGIN-LEFT: 18pt; MARGIN-RIGHT: 0pt" align="justify"><font style="FONT-STYLE: italic; DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">Other Legal Proceedings</font></div><div style="TEXT-INDENT: 0pt; DISPLAY: block"><br /></div><div style="TEXT-INDENT: 27pt; DISPLAY: block; MARGIN-LEFT: 0pt; MARGIN-RIGHT: 0pt" align="justify"><font style="DISPLAY: inline; FONT-FAMILY: Times New Roman; FONT-SIZE: 10pt">We are parties to a number of other legal proceedings, incident to our normal business activities.&#160;&#160;These include, for example, contract disputes, personal injury claims, property damage claims, environmental issues, and employment and safety matters.<font style="DISPLAY: inline; FONT-WEIGHT: bold">&#160;</font>While we cannot predict th e outcome of any of these proceedings, based on our current estimates we do not believe that any liability arising from these matters individually or in the aggregate should have a material adverse impact upon our consolidated cash flows, results of operations or financial condition.&#160;&#160;It is possible, however, that the ultimate liabilities in the future with respect to these lawsuits and claims, in the aggregate, may be materially adverse to our cash flows, results of operations or financial condition.</font></div> (16)&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;&#160;ContingenciesWest Virginia FloodingSince August 2004, five of our subsidiaries have been false false false us-types:textBlockItemType textblock Includes disclosure of commitments and contingencies. 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Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Staff Accounting Bulletin (SAB) -Number Topic 6 -Section I -Subsection 7 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 109 -Paragraph 45 -Subparagraph b Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 Reference 4: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 109 -Paragraph 289 Reference 5: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 08 -Paragraph h -Article 4 false 10 3 us-gaap_GainLossOnSaleOfPropertyPlantEquipment us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false -3284000 -3284 false false false 2 false true false false -12017000 -12017 false false false xbrli:monetaryItemType monetary The difference between the sale price or salvage price and the book value of a property, plant, and equipment asset that was sold or retired during the reporting period. This element refers to the gain (loss). Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 11 3 mee_GainOnReserveExchanges mee false na duration Gain or loss recorded from exchange of coal properties, includes the realized gains (losses) on the exchange of proved and... false false false false false false false false false false false terselabel false 1 false true false false -6879000 -6879 false false false 2 false true false false -24922000 -24922 false false false xbrli:monetaryItemType monetary Gain or loss recorded from exchange of coal properties, includes the realized gains (losses) on the exchange of proved and unproved coal properties. No authoritative reference available. false 12 3 mee_GainOnInsuranceRecovery mee false credit duration The excess insurance recoveries compared to the recorded loss incurred from an insured event (including a conversion of... false false false false false false false false false false false label false 1 false true false false -5810000 -5810 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The excess insurance recoveries compared to the recorded loss incurred from an insured event (including a conversion of nonmonetary assets to monetary assets). An excess would occur from recovery of lost profits, and recoveries at current replacement cost less carrying amounts of assets that were damaged or destroyed. No authoritative reference available. false 13 3 us-gaap_UnrealizedGainLossOnDerivatives us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false -5363000 -5363 false false false 2 false true false false -22598000 -22598 false false false xbrli:monetaryItemType monetary The increases (decreases) in the market value of derivative instruments, including options, swaps, futures, and forward contracts, which were included in earnings in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 14 3 us-gaap_GainLossOnInvestments us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false -4662000 -4662 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary This item represents the net total realized and unrealized gain (loss) included in earnings for the period as a result of selling or holding marketable securities categorized as trading, available-for-sale, or held-to-maturity, including the unrealized holding gain or loss of held-to-maturity securities transferred to the trading security category and the cumulative unrealized gain or loss which was included in other comprehensive income (a separate component of shareholders' equity) for available-for-sale securities transferred to trading securities during the period. Additionally, this item would include any gains or losses realized during the period from the sale of investments accounted for under the cost method of accounting and losses recognized for other than temporary impairments of the subject investments. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 03 -Paragraph 7 -Article 5 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 115 -Paragraph 13, 22 false 15 3 us-gaap_AssetRetirementObligationAccretionExpense us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 13121000 13121 false false false 2 false true false false 10515000 10515 false false false xbrli:monetaryItemType monetary Amount of accretion expense recognized in the income statement during the period that is associated with asset retirement obligations. Accretion expense measures and incorporates changes due to the passage of time into the carrying amount of the liability. Such accretion expense representing changes in the liability for an asset retirement obligation due to passage of time is the result of applying an interest method of allocation to the amount of the liability at the beginning of the period. The interest rate used to measure that change shall be the credit-adjusted risk-free rate that existed when the liability, or portion thereof, was initially measured. That amount shall be recognized as an increase in the carrying amount of the liability and as an expense classified as an operating item in the statement of income. Accretion expense shall not be considered to be interest cost for purposes of capitalization of interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 143 -Paragraph 13, 14 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 143 -Paragraph 22 -Subparagraph c(3) false 16 3 us-gaap_ProvisionForOtherLosses us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 4953000 4953 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The provision charged to earnings in the period, the offset to which is either added to or deducted from the allowance account, for the purpose of reducing receivables, other than loans, leases, or credit losses, to an amount that approximates their net realizable value (the amount expected to be collected); includes provision for losses associated with foreclosed assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 03 -Paragraph 5 -Article 5 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 04 -Paragraph 11 -Article 9 false 17 3 us-gaap_OtherAssetImpairmentCharges us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 63577000 63577 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The charge against earnings resulting from the write down of long lived assets other than goodwill due to the difference between the carrying value and lower fair value. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 18 3 us-gaap_IncreaseDecreaseInOperatingCapitalAbstract us-gaap true na duration No definition available. false false false false false true false false false false false false 1 false false false false 0 0 false false false 2 false false false false 0 0 false false false xbrli:stringItemType string No definition available. false 19 4 us-gaap_IncreaseDecreaseInAccountsReceivable us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false -118943000 -118943 false false false 2 false true false false 49319000 49319 false false false xbrli:monetaryItemType monetary The net change during the reporting period in amount due within one year (or one business cycle) from customers for the credit sale of goods and services. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 20 4 us-gaap_IncreaseDecreaseInInventories us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false 16082000 16082 false false false 2 false true false false 3339000 3339 false false false xbrli:monetaryItemType monetary The net change during the reporting period in the aggregate value of all inventory held by the reporting entity, associated with underlying transactions that are classified as operating activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 21 4 mee_IncreaseDecreaseInOtherAssets mee false na duration The net change during reporting period in other assets not otherwise defined in taxonomy. false false false false false false false false false false false terselabel false 1 false true false false 42632000 42632 false false false 2 false true false false -58605000 -58605 false false false xbrli:monetaryItemType monetary The net change during reporting period in other assets not otherwise defined in taxonomy. No authoritative reference available. false 22 4 us-gaap_IncreaseDecreaseInAccountsPayable us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 38215000 38215 false false false 2 false true false false -75545000 -75545 false false false xbrli:monetaryItemType monetary The net change during the reporting period in the aggregate amount of obligations due within one year (or one business cycle). This may include trade payables, amounts due to related parties, royalties payable, and other obligations. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 23 4 us-gaap_IncreaseDecreaseInAccruedIncomeTaxesPayable us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false -2001000 -2001 false false false 2 false true false false 8110000 8110 false false false xbrli:monetaryItemType monetary The net change during the period in the amount of cash payments due to taxing authorities for taxes that are based on the reporting entity's earnings. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 24 4 us-gaap_IncreaseDecreaseInAccruedLiabilities us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 73336000 73336 false false false 2 false true false false 3020000 3020 false false false xbrli:monetaryItemType monetary The net change during the reporting period in the aggregate amount of expenses incurred but not yet paid. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 25 4 mee_IncreaseInOtherNoncurrentLiabilities mee false na duration The net change during reporting period in other obligations not otherwise defined in taxonomy false false false false false false false false false false false terselabel false 1 false true false false 43585000 43585 false false false 2 false true false false 17980000 17980 false false false xbrli:monetaryItemType monetary The net change during reporting period in other obligations not otherwise defined in taxonomy No authoritative reference available. false 26 4 us-gaap_IncreaseDecreaseInPensionPlanObligations us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 2129000 2129 false false false 2 false true false false 16140000 16140 false false false xbrli:monetaryItemType monetary The net change during the reporting period in the amount due to fund retirement benefits to employees, retired and disabled former employees. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 27 4 us-gaap_IncreaseDecreaseInAssetRetirementObligations us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false -4941000 -4941 false false false 2 false true false false -3431000 -3431 false false false xbrli:monetaryItemType monetary The net change during the reporting period in the carrying amount of asset retirement obligations. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 false 28 4 us-gaap_NetCashProvidedByUsedInOperatingActivities us-gaap true na duration No definition available. false false false false false false false false false false false totallabel false 1 false true false false 268062000 268062 false false false 2 false true false false 232110000 232110 false false false xbrli:monetaryItemType monetary The net cash from (used in) all of the entity's operating activities, including those of discontinued operations, of the reporting entity. Operating activities generally involve producing and delivering goods and providing services. Operating activity cash flows include transactions, adjustments, and changes in value that are not defined as investing or financing activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 28 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 26 true 29 1 us-gaap_NetCashProvidedByUsedInInvestingActivitiesAbstract us-gaap true na duration No definition available. false false false false false true false false false false false false 1 false false false false 0 0 false false false 2 false false false false 0 0 false false false xbrli:stringItemType string No definition available. false 30 2 us-gaap_PaymentsToAcquireBusinessesNetOfCashAcquired us-gaap true credit duration No definition available. false false false false false false false false false false false false 1 false true false false 629977000 629977 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The cash outflow associated with the acquisition of a business, net of the cash acquired from the purchase. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 15, 17 false 31 2 us-gaap_PaymentsToAcquirePropertyPlantAndEquipment us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false -278523000 -278523 false false false 2 false true false false -222970000 -222970 false false false xbrli:monetaryItemType monetary The cash outflow associated with the acquisition of long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale; includes cash outflows to pay for construction of self-constructed assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 15 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 17 -Subparagraph c false 32 2 us-gaap_PaymentsForProceedsFromShortTermInvestments us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false 15526000 15526 false false false 2 false true false false 24262000 24262 false false false xbrli:monetaryItemType monetary The net amount paid (received) by the reporting entity through acquisition (sale/maturities) of short-term investments with an original maturity that is three months or less which qualify for treatment as an investing activity based on management's intention and intended by management to be liquidated, if necessary, within the current operating cycle. Includes cash flows from securities classified as trading securities that were acquired for reasons other than sale in the short-term. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 13 false 33 2 us-gaap_ProceedsFromSaleOfProductiveAssets us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 3041000 3041 false false false 2 false true false false 15704000 15704 false false false xbrli:monetaryItemType monetary The cash inflow from the sale of property, plant and equipment (capital expenditures), software, and other intangible assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 15 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 16 -Subparagraph c false 34 2 us-gaap_ProceedsFromInsuranceSettlementInvestingActivities us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 9605000 9605 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The cash inflow from the amounts received by the insured under the terms of an insurance contract settlement. This element pertains only to insurance proceeds related to investments, for example fixed assets. It excludes insurance settlements classified as operating cash flows. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 22 -Subparagraph c false 35 2 us-gaap_NetCashProvidedByUsedInInvestingActivities us-gaap true debit duration No definition available. false false false false false false false false false false false totallabel false 1 false true false false -880328000 -880328 false false false 2 false true false false -183004000 -183004 false false false xbrli:monetaryItemType monetary The net cash inflow (outflow) from investing activity. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 26 true 36 1 us-gaap_NetCashProvidedByUsedInFinancingActivitiesAbstract us-gaap true na duration No definition available. false false false false false true false false false false false false 1 false false false false 0 0 false false false 2 false false false false 0 0 false false false xbrli:stringItemType string No definition available. false 37 2 us-gaap_PaymentsToAcquireRestrictedInvestments us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false 466707000 466707 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The cash outflow to acquire investments (not to include restricted cash) that are pledged or subject to withdrawal restrictions. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 15, 17 false 38 2 us-gaap_PaymentsForRepurchaseOfCommonStock us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false -31822000 -31822 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The cash outflow to reacquire common stock during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 18 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 20 -Subparagraph a false 39 2 us-gaap_RepaymentsOfLongTermCapitalLeaseObligations us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false -1184000 -1184 false false false 2 false true false false -2175000 -2175 false false false xbrli:monetaryItemType monetary The cash outflow for the obligation for lease meeting the criteria for capitalization (with maturities exceeding one year or beyond the operating cycle of the entity, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 26, 31 false 40 2 us-gaap_EarlyRepaymentOfSeniorDebt us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false -21949000 -21949 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The cash outflow for the extinguishment of borrowing, with the highest claim on the assets of the entity in case of bankruptcy or liquidation, before its maturity. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 18 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 20 -Subparagraph b false 41 2 mee_RedemptionOfConvertibleSeniorNotes mee false debit duration Redemption of 4.75% convertible senior notes false false false false false false false false false false false terselabel false 1 false true false false 0 0 false false false 2 false true false false -70000 -70 false false false xbrli:monetaryItemType monetary Redemption of 4.75% convertible senior notes No authoritative reference available. false 42 2 us-gaap_SaleLeasebackTransactionNetProceeds us-gaap true debit duration No definition available. false false false false false false false false false false false label false 1 false true false false 16477000 16477 false false false 2 false true false false 0 0 false false false xbrli:monetaryItemType monetary The gross proceeds received from the asset(s) sold in connection with the transaction involving the sale of property to another party and the lease of the property back to the seller less the costs incurred in connection with the transaction, such as closing and deferred financing costs. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 98 -Section Appendix A -Paragraph 28, 29 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 13 -Paragraph 33 false 43 2 us-gaap_PaymentsOfDividends us-gaap true credit duration No definition available. false false false false false false false false false false true negated false 1 false true false false -17356000 -17356 false false false 2 false true false false -15283000 -15283 false false false xbrli:monetaryItemType monetary The cash outflow from the entity's earnings to the shareholders. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 18 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 20 -Subparagraph a false 44 2 us-gaap_ProceedsFromStockOptionsExercised us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 11960000 11960 false false false 2 false true false false 1190000 1190 false false false xbrli:monetaryItemType monetary The cash inflow associated with the amount received from holders exercising their stock options. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 18 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 123R -Paragraph A240 -Subparagraph i Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 19 -Subparagraph a false 45 2 us-gaap_ExcessTaxBenefitFromShareBasedCompensationFinancingActivities us-gaap true debit duration No definition available. false false false false false false false false false false false false 1 false true false false 625000 625 false false false 2 false true false false 227000 227 false false false xbrli:monetaryItemType monetary Reductions in the entity's income taxes that arise when compensation cost (from non-qualified share-based compensation) recognized on the entity's tax return exceeds compensation cost from share-based compensation recognized in financial statements. This element represents the cash inflow reported in the enterprise's financing activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 123R -Paragraph A240 -Subparagraph i Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Emerging Issues Task Force (EITF) -Number 00-15 -Paragraph 3 false 46 2 us-gaap_NetCashProvidedByUsedInFinancingActivities us-gaap true debit duration No definition available. false false false false false false false false false false false totallabel false 1 false true false false 423458000 423458 false false false 2 false true false false -16111000 -16111 false false false xbrli:monetaryItemType monetary The net cash inflow (outflow) from financing activity for the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 26 true 47 1 us-gaap_CashAndCashEquivalentsPeriodIncreaseDecrease us-gaap true na duration No definition available. false false false false false false false false false false false totallabel false 1 false true false false -188808000 -188808 false false false 2 false true false false 32995000 32995 false false false xbrli:monetaryItemType monetary The net change between the beginning and ending balance of cash and cash equivalents. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 26 true 48 1 us-gaap_CashAndCashEquivalentsAtCarryingValue us-gaap true debit instant No definition available. false false false false false false false false true false false periodstartlabel false 1 false true false false 665762000 665762 false false false 2 false true false false 606997000 606997 false false false xbrli:monetaryItemType monetary Includes currency on hand as well as demand deposits with banks or financial institutions. It also includes other kinds of accounts that have the general characteristics of demand deposits in that the Entity may deposit additional funds at any time and also effectively may withdraw funds at any time without prior notice or penalty. Cash equivalents, excluding items classified as marketable securities, include short-term, highly liquid investments that are both readily convertible to known amounts of cash, and so near their maturity that they present minimal risk of changes in value because of changes in interest rates. Generally, only investments with original maturities of three months or less qualify under that definition. Original maturity means original maturity to the entity holding the investment. For example, both a three-month US Treasury bill and a three-year Treasury note purchased three months from maturity qualify as cash equivalents. However, a Treasury note purchased th ree years ago does not become a cash equivalent when its remaining maturity is three months. Compensating balance arrangements that do not legally restrict the withdrawal or usage of cash amounts may be reported as Cash and Cash Equivalents, while legally restricted deposits held as compensating balances against borrowing arrangements, contracts entered into with others, or company statements of intention with regard to particular deposits should not be reported as cash and cash equivalents. Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 7, 26 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 8, 9 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 95 -Paragraph 7 -Footnote 1 Reference 4: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 02 -Paragraph 1 -Article 5 false 49 1 us-gaap_CashAndCashEquivalentsAtCarryingValue us-gaap true debit instant No definition available. false false false false false false false false false true false periodendlabel false 1 true true false false 476954000 476954 false false false 2 true true false false 639992000 639992 false false false xbrli:monetaryItemType monetary Includes currency on hand as well as demand deposits with banks or financial institutions. It also includes other kinds of accounts that have the general characteristics of demand deposits in that the Entity may deposit additional funds at any time and also effectively may withdraw funds at any time without prior notice or penalty. Cash equivalents, excluding items classified as marketable securities, include short-term, highly liquid investments that are both readily convertible to known amounts of cash, and so near their maturity that they present minimal risk of changes in value because of changes in interest rates. Generally, only investments with original maturities of three months or less qualify under that definition. Original maturity means original maturity to the entity holding the investment. For example, both a three-month US Treasury bill and a three-year Treasury note purchased three months from maturity qualify as cash equivalents. However, a Treasury note purchased th ree years ago does not become a cash equivalent when its remaining maturity is three months. Compensating balance arrangements that do not legally restrict the withdrawal or usage of cash amounts may be reported as Cash and Cash Equivalents, while legally restricted deposits held as compensating balances against borrowing arrangements, contracts entered into with others, or company statements of intention with regard to particular deposits should not be reported as cash and cash equivalents. 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Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Regulation S-X (SX) -Number 210 -Section 02 -Paragraph 22 -Article 5 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher SEC -Name Staff Accounting Bulletin (SAB) -Number Topic 6 -Section H false 28 3 us-gaap_DeferredTaxLiabilitiesNoncurrent us-gaap true credit instant No definition available. false false false false false false false false false false false false 1 false true false false 258605000 258605 false false false 2 false true false false 209230000 209230 false false false xbrli:monetaryItemType monetary Represents the noncurrent portion of deferred tax liabilities, which result from applying the applicable tax rate to net taxable temporary differences pertaining to each jurisdiction to which the entity is obligated to pay income tax. 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