Edgar Filing: International Coal Group, Inc.

frm10-q.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, 2009

¨	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. 001-32679

International Coal Group, Inc.

(Exact Name of Registrant as Specified in Its Charter)

Delaware		20-2641185
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

300 Corporate Centre Drive Scott Depot, West Virginia		25560
(Address of Principal Executive Offices)		(Zip Code)

(304) 760-2400

(Registrant’s Telephone Number, Including Area Code)

N/A

(Former Name, Former Address and Former Fiscal Year, if Changed Since Last Report)

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨ 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.

Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨ 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

APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PRECEDING FIVE YEARS:

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ¨ No ¨

APPLICABLE ONLY TO CORPORATE ISSUERS:

Number of shares of the Registrant’s Common Stock, $0.01 par value, outstanding as of November 1, 2009—154,154,964.

TABLE OF CONTENTS

		Page
	PART I—FINANCIAL INFORMATION
Item 1.	Condensed Consolidated Financial Statements	3
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	40
Item 4.	Controls and Procedures	41
	PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	41
Item 1A.	Risk Factors	41
Item 6.	Exhibits	44

PART I

Item 1.

Condensed Consolidated Financial Statements

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

Condensed Consolidated Balance Sheets (Unaudited)

(Dollars in thousands, except per share amounts)

	September 30, 2009			December 31, 2008
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	97,660		$	63,930
Accounts receivable, net of allowances of $222 and $1,516		80,005			75,321
Inventories, net		78,576			58,788
Deferred income taxes		16,817			17,649
Prepaid insurance		3,020			13,380
Income taxes receivable		11			8,030
Prepaid expenses and other		8,834			10,893
Total current assets		284,923			247,991

PROPERTY, PLANT, EQUIPMENT AND MINE DEVELOPMENT, net		1,039,934			1,069,297
DEBT ISSUANCE COSTS, net		9,576			10,462
ADVANCE ROYALTIES, net		18,061			17,462
OTHER NON-CURRENT ASSETS		6,701			5,435
Total assets	$	1,359,195		$	1,350,647

LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	56,665		$	75,810
Short-term debt		269			4,741
Current portion of long-term debt and capital lease		17,998			15,319
Current portion of reclamation and mine closure costs		10,118			11,139
Current portion of employee benefits		3,359			3,359
Accrued expenses and other		72,026			87,704
Total current liabilities		160,435			198,072

LONG-TERM DEBT AND CAPITAL LEASE		426,223			417,551
RECLAMATION AND MINE CLOSURE COSTS		69,812			68,107
EMPLOYEE BENEFITS		69,553			61,194
DEFERRED INCOME TAXES		56,489			49,403
BELOW-MARKET COAL SUPPLY AGREEMENTS		30,589			43,888
OTHER NON-CURRENT LIABILITIES		4,001			6,195
Total liabilities		817,102			844,410

COMMITMENTS AND CONTINGENCIES

STOCKHOLDERS’ EQUITY:
Preferred stock – par value $0.01, 200,000,000 shares authorized, none issued		—			—
Common stock – par value $0.01, 2,000,000,000 shares authorized, 154,159,183 and 154,151,862 shares issued and outstanding, respectively, as of September 30, 2009 and 153,322,245 shares issued and outstanding, as of December 31, 2008		1,542			1,533
Treasury stock		(14	)		—
Additional paid-in capital		659,955			656,997
Accumulated other comprehensive loss		(5,028	)		(5,157	)
Retained deficit		(114,380	)		(147,171	)
Total International Coal Group, Inc. stockholders’ equity		542,075			506,202
Noncontrolling interest		18			35
Total stockholders’ equity		542,093			506,237
Total liabilities and stockholders’ equity	$	1,359,195		$	1,350,647

See notes to condensed consolidated financial statements.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

Condensed Consolidated Statements of Operations (Unaudited)

(Dollars in thousands, except per share amounts)

	Three months ended September 30,						Nine months ended September 30,
	2009			2008			2009			2008
REVENUES:
Coal sales revenues	$	246,788		$	282,250		$	775,281		$	761,963
Freight and handling revenues		5,777			12,339			20,452			35,492
Other revenues		44,057			14,610			83,652			41,554
Total revenues		296,622			309,199			879,385			839,009
COSTS AND EXPENSES:
Cost of coal sales		208,083			240,204			647,372			666,598
Freight and handling costs		5,777			12,339			20,452			35,492
Cost of other revenues		12,724			9,690			28,690			27,847
Depreciation, depletion and amortization		26,996			24,227			79,294			70,878
Selling, general and administrative		5,351			8,396			24,632			27,051
(Gain) loss on sale of assets, net		2			(6,383	)		(3,184	)		(32,675	)
Total costs and expenses		258,933			288,473			797,256			795,191
Income from operations		37,689			20,726			82,129			43,818
INTEREST EXPENSE, net		(13,409	)		(9,455	)		(39,641	)		(30,819	)
Income before income taxes		24,280			11,271			42,488			12,999
INCOME TAX EXPENSE		(5,566	)		(1,949	)		(9,674	)		(1,815	)
Net income		18,714			9,322			32,814			11,184
Net (income) loss attributable to noncontrolling interest		2			2			(23	)		(3	)
Net income attributable to International Coal Group, Inc.	$	18,716		$	9,324		$	32,791		$	11,181

Earnings per share:
Basic	$	0.12		$	0.06		$	0.21		$	0.07
Diluted	$	0.12		$	0.06		$	0.21		$	0.07
Weighted-average common shares outstanding:
Basic		152,998,598			152,761,955			152,869,195			152,587,831
Diluted		155,214,868			153,025,680			154,289,039			152,745,474

See notes to condensed consolidated financial statements.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

Condensed Consolidated Statements of Cash Flows (Unaudited)

(Dollars in thousands)

	Nine months ended September 30,
	2009			2008
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	32,814		$	11,184
Adjustments to reconcile net income to net cash from operating activities:
Depreciation, depletion and amortization		79,294			70,878
Amortization of deferred finance costs and debt discount		5,183			4,559
Provision for bad debt		(1,294	)		(522	)
Compensation expense on equity instruments		2,967			3,216
Gain on sale of assets, net		(3,184	)		(32,675	)
Deferred income taxes		8,416			1,680
Amortization of accumulated postretirement benefit obligation		216			323
Changes in assets and liabilities:
Accounts receivable		(3,390	)		(33,337	)
Inventories		(19,788	)		(7,172	)
Prepaid expenses and other		20,438			3,007
Other non-current assets		246			1,969
Accounts payable		(14,779	)		5,625
Accrued expenses and other		(15,798	)		13,492
Reclamation and mine closure costs		1,231			(1,961	)
Other liabilities		(1,532	)		4,202
Net cash from operating activities		91,040			44,468
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from the sale of assets		3,218			8,688
Additions to property, plant, equipment and mine development		(48,695	)		(93,632	)
Cash paid related to acquisitions and net assets acquired		—			(603	)
(Deposits) withdrawals of restricted cash		(1,535	)		18
Net cash from investing activities		(47,012	)		(85,529	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments on short-term debt		(4,472	)		—
Borrowings on long-term debt and capital lease		9,086			—
Repayments on long-term debt and capital lease		(13,682	)		(3,828	)
Purchases of treasury stock		(14	)		—
Proceeds from stock options exercised		—			149
Debt issuance costs		(1,216	)		(188	)
Net cash from financing activities		(10,298	)		(3,867	)
NET CHANGE IN CASH AND CASH EQUIVALENTS		33,730			(44,928	)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		63,930			107,150
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	97,660		$	62,222

Supplemental information:
Cash paid for interest (net of amount capitalized)	$	43,292		$	35,859
Cash received for income taxes, net	$	7,164		$	—
Supplemental disclosure of non-cash items:
Purchases of property, plant, equipment and mine development through accounts payable	$	8,576		$	13,481
Purchases of property, plant, equipment and mine development through financing arrangements	$	12,866		$	17,294
Assets acquired through assumption of liabilities	$	—		$	17,464
Assets acquired through the exchange of coal reserves	$	—		$	22,608

See notes to condensed consolidated financial statements.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

(1) Basis of Presentation

The accompanying interim condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial reporting and include the accounts of International Coal Group, Inc. and its subsidiaries (the “Company”) and its controlled affiliates. Significant intercompany transactions, profits and balances have been eliminated in consolidation. The Company accounts for its undivided interest in coalbed methane wells using the proportionate consolidation method, whereby its share of assets, liabilities, revenues and expenses are included in the appropriate classification in the financial statements.

The accompanying interim condensed consolidated financial statements as of September 30, 2009 and for the three and nine months ended September 30, 2009 and 2008, and the notes thereto, are unaudited. However, in the opinion of management, these financial statements reflect all normal, recurring adjustments necessary for a fair presentation of the results of the periods presented. The balance sheet information as of December 31, 2008 has been derived from the Company’s audited consolidated balance sheet. These statements should be read in conjunction with the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008. The results of operations for the three and nine months ended September 30, 2009 are not necessarily indicative of the results to be expected for future quarters or for the year ending December 31, 2009.

(2) Summary of Significant Accounting Policies and General

Fair Value Measurements—In September 2006, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Codification (“ASC”) Topic 820, Fair Value Measurements and Disclosures (“ASC 820”). ASC 820 clarified the definition of fair value, established a framework for measuring fair value and expanded the disclosures on fair value measurements. Additionally, ASC 820 permitted delayed adoption for certain non-financial assets and liabilities, which are not recognized at fair value on a recurring basis, until fiscal years, and interim periods within those fiscal years, beginning after November 15, 2008. ASC 820 demonstrated how the fair value of a financial asset is determined when the market for that financial asset is inactive, provided guidance on estimating fair value when the volume and level of activity for an asset or liability have significantly decreased in relation to normal market activity for the asset or liability and provided guidance on circumstances that may indicate that a transaction is not orderly. ASC 820 is effective for fiscal years beginning after November 15, 2007. Adoption of ASC 820 did not have a material impact on the Company’s financial position, results of operations or cash flows.

Convertible Debt—In May 2008, the FASB issued ASC Subtopic 470-20, Debt with Conversion and Other Options (“ASC 470-20”). ASC 470-20 required the liability and equity components of convertible debt instruments that may be settled in cash upon conversion to be separately accounted for in a manner that reflects the issuer’s nonconvertible debt borrowing rate. To allocate the proceeds from a convertible debt offering in this manner, a company determines the carrying amount of the liability component, which is based on the fair value of a similar liability, excluding any embedded conversion options. The resulting debt discount is amortized as additional non-cash interest expense over the period during which the debt is expected to be outstanding. ASC 470-20 was effective for financial statements for fiscal years beginning after December 15, 2008, and interim periods within those fiscal years, and has been applied retrospectively for all periods presented. The Company has determined its non-convertible borrowing rate would have been 11.7% at issuance. The effect of adoption of ASC 470-20 was as follows:

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

	December 31, 2008
	As Previously Reported			Adjustment			As Adjusted
Property, plant, equipment and mine development	$	1,068,146		$	1,151		$	1,069,297
Debt issuance costs, net		10,635			(173	)		10,462
Total assets		1,349,669			978			1,350,647

Long-term debt and capital lease		434,920			(17,369	)		417,551
Deferred tax liability		42,468			6,935			49,403
Total liabilities		854,844			(10,434	)		844,410

Additional paid-in capital		643,480			13,517			656,997
Retained deficit		(145,066	)		(2,105	)		(147,171	)
Total International Coal Group, Inc. stockholders’ equity		494,790			11,412			506,202
Total liabilities and stockholders’ equity		1,349,669			978			1,350,647

	Three months ended September 30, 2008									Nine months ended September 30, 2008
	As Previously Reported			Adjustment			As Adjusted			As Previously Reported			Adjustment			As Adjusted
Interest expense, net	$	(8,837	)	$	(618	)	$	(9,455	)	$	(29,019	)	$	(1,800	)	$	(30,819	)
Income tax expense		(2,183	)		234			(1,949	)		(2,496	)		681			(1,815	)
Net income attributable to International Coal Group, Inc.		9,708			(384	)		9,324			12,300			(1,119	)		11,181
Earnings per share:
Basic and diluted	$	0.06		$	—		$	0.06		$	0.08		$	(0.01	)	$	0.07

Business Combinations—In December 2007, the FASB issued ASC Topic 805, Business Combinations (“ASC 805”). ASC 805 will significantly change the accounting for business combinations. Under ASC 805, an acquiring entity will be required to recognize all the assets acquired and liabilities assumed in a transaction at the acquisition-date fair value with limited exceptions. ASC 805 will change the accounting treatment for certain specific acquisition-related items including: (i) expensing acquisition-related costs as incurred, (ii) valuing noncontrolling interests at fair value at the acquisition date and (iii) expensing restructuring costs associated with an acquired business. ASC 805 also includes a substantial number of new disclosure requirements. ASC 805 is to be applied to any business combination for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. Adoption of ASC 805 will impact the accounting for the Company’s future business combinations, as well as for tax uncertainties and valuation allowances from prior acquisitions.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Noncontrolling Interests—In December 2007, the FASB issued ASC Topic 810, Consolidation (“ASC 810”). ASC 810 establishes new accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. It clarifies that a noncontrolling interest in a subsidiary (minority interest) is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements and separate from the parent company’s equity. Among other requirements, this statement requires consolidated net income to be reported at amounts that include the amounts attributable to both the parent and the noncontrolling interest. It also requires disclosure, on the face of the consolidated statement of operations, of the amounts of consolidated net income attributable to the parent and to the noncontrolling interest. ASC 810 is effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Adoption of ASC 810 impacted the presentation of noncontrolling interest in the Company’s balance sheets and statements of operations and cash flows. The impact of the changes in presentation was not material.

Derivative Instruments—In March 2008, the FASB issued ASC Topic 815, Derivatives and Hedging (“ASC 815”). ASC 815 requires additional disclosures for derivative instruments and hedging activities that include how and why an entity uses derivatives, how these instruments and the related hedged items are accounted for under ASC 815, and related interpretations, and how derivative instruments and related hedged items affect the entity’s financial position, results of operations and cash flows. ASC 815 is effective for fiscal years, and interim periods within those fiscal years, beginning after November 15, 2008. Adoption of ASC 815 did not impact the footnotes accompanying the Company’s consolidated financial statements.

Share-Based Payments—In June 2008, the FASB issued ASC Topic 260, Earnings Per Share (“ASC 260”). ASC 260 clarifies that all outstanding unvested share-based payment awards that contain rights to nonforfeitable dividends participate in undistributed earnings with common shareholders. Awards of this nature are considered participating securities and the two-class method of computing basic and diluted earnings per share must be applied. ASC 260 is effective for fiscal years beginning after December 15, 2008. Adoption of ASC 260 did not have a material impact on the Company’s financial position, results of operations or cash flows.

Financial Instruments—In June 2008, the FASB ratified ASC Subtopic 815-40, Contracts in Entity’s Own Equity (“ASC 815-40”). ASC 815-40 provides that an entity should use a two-step approach to evaluate whether an equity-linked financial instrument (or embedded feature) is indexed to its own stock, including evaluating the instrument’s contingent exercise and settlement provisions. It also clarifies the impact of foreign currency denominated strike prices and market-based employee stock option valuation instruments on the evaluation. ASC 815-40 is effective for fiscal years beginning after December 15, 2008. Adoption of ASC 815-40 did not have a material impact on the Company’s financial position, results of operations or cash flows.

Impairments—In April 2009, the FASB issued ASC Topic 320, Investments–Debt and Equity Securities (“ASC 320”). ASC 320 modifies the other-than-temporary impairment guidance for debt securities through increased consistency in the timing of impairment recognition and enhanced disclosures related to the credit and noncredit components of impaired debt securities that are not expected to be sold. In addition, increased disclosures are required for both debt and equity securities regarding expected cash flows, credit losses and an aging of securities with unrealized losses. ASC 320 is effective for interim and annual reporting periods that end after June 15, 2009. Adoption of ASC 320 did not impact the Company’s financial position, results of operations or cash flows.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Fair Value Instruments—In April 2009, the FASB issued ASC Topic 825, Financial Instruments (“ASC 825”). ASC 825 requires fair value disclosures for financial instruments that are not reflected in the condensed consolidated balance sheets at fair value to be disclosed on a quarterly basis, providing quantitative and qualitative information about fair value estimates. ASC 825 is effective for interim reporting periods ending after June 15, 2009. Adoption of ASC 825 did not impact the Company’s financial position, results of operations or cash flows; however, adoption did result in additional information being included in the footnotes accompanying the Company’s consolidated financial statements. See Note 9.

Subsequent Events—In May 2009, the FASB issued ASC Topic 855, Subsequent Events (“ASC 855”). ASC 855 establishes principles and requirements for events that occur after the balance sheet date, but before the issuance of the financial statements. ASC 855 requires disclosure of the date through which subsequent events have been evaluated and disclosure of certain non-recognized subsequent events. ASC 855 is effective for interim and annual periods ending after June 15, 2009. Adoption of ASC 855 did not have a material impact on the Company’s financial position, results of operations or cash flows.

Variable Interest Entities—In June 2009, the FASB issued ASC Topic 810, Consolidation (“ASC 810”) to improve financial reporting by enterprises involved with variable interest entities and to provide more relevant and reliable information to users of financial statements. ASC 810 is effective as of the first fiscal year beginning after November 15, 2009. The Company does not believe that adoption of ASC 810 will materially impact its financial position, results of operations or cash flows.

FASB Codification—In June 2009, the FASB issued ASC Topic 105, Generally Accepted Accounting Principles (“ASC 105”). ASC 105 makes the FASB Accounting Standards Codification the single source of authoritative U.S. accounting and reporting standards, but it does not change U.S. generally accepted accounting principles. ASC 105 is effective for interim and annual periods ending after September 15, 2009. Adoption of ASC 105 did not have a material impact on the Company’s financial condition, results of operations or cash flows.

Corporate Vacation Policy—In June 2009, the Company changed its policy related to when employees are credited with vacation time. Under the original policy, employees earned their vacation in the year prior to vesting, and were vested with 100% of their annual vacation time on January 1st of each year. Under the revised policy, employees are vested in their vacation time ratably throughout the year as it is earned. If the Company continued to account for vacation under the old policy, it would have recognized additional cost of coal sales, cost of other revenues and selling, general and administrative expenses of $1,775, $102 and $113, respectively, for the three months ended September 30, 2009 and $5,323, $332 and $381, respectively, for the nine months ended September 30, 2009.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

(3) Inventories

Inventories consisted of the following:

	September 30, 2009			December 31, 2008
Coal	$	46,322		$	28,436
Parts and supplies		34,305			32,159
Reserve for obsolescence–parts and supplies		(2,051	)		(1,807	)
Total	$	78,576		$	58,788

(4) Property, Plant, Equipment and Mine Development

Property, plant, equipment and mine development are summarized by major classification as follows:

	September 30, 2009			December 31, 2008
Coal lands and mineral rights	$	586,508		$	586,512
Plant and equipment		604,719			571,083
Mine development		193,576			181,876
Land and land improvements		24,569			24,119
Coalbed methane well development costs		14,889			14,889
		1,424,261			1,378,479
Less accumulated depreciation, depletion and amortization		(384,327	)		(309,182	)
Net property, plant, equipment and mine development	$	1,039,934		$	1,069,297

Depreciation, depletion and amortization expense related to property, plant, equipment and mine development was $27,431 and $25,852 for the three months ended September 30, 2009 and 2008, respectively, and $84,864 and $77,959 for the nine months ended September 30, 2009 and 2008, respectively.

In June 2008, the Company exchanged coal reserves with a third-party. In addition to reserves, the Company received $3,000 in cash. As a result, the Company recognized a pre-tax gain of $24,633 based upon the fair value of the underlying assets received in the exchange, which is included in gain on sale of assets in its statement of operations for the nine months ended September 30, 2008. Additionally, in September 2008, the Company exchanged certain property resulting in the recognition of a $975 pre-tax gain based upon the fair value of the underlying assets given up in the exchange. The gain is included in gain on sale of assets in the Company’s statement of operations for the three and nine months ended September 30, 2008.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

(5) Debt

Long-Term Debt and Capital Lease

Long-term debt and capital lease consisted of the following:

	September 30, 2009			December 31, 2008
9.00% Convertible Senior Notes, due 2012, net of debt discount of $14,287 and $17,369, respectively	$	210,713		$	207,631
10.25% Senior Notes, due 2014		175,000			175,000
Equipment notes		54,566			43,378
Capital lease and other		3,942			6,861
Total		444,221			432,870
Less current portion		(17,998	)		(15,319	)
Long-term debt and capital lease	$	426,223		$	417,551

Convertible senior notes—In 2007, the Company completed a private offering of $225,000 aggregate principal amount of 9.00% Convertible Senior Notes (the “Convertible Notes”) due 2012. The Convertible Notes are the Company’s senior unsecured obligations and are guaranteed on a senior unsecured basis by the Company’s material current and future domestic subsidiaries. The Convertible Notes and the related guarantees rank equal in right of payment to all of the Company’s and the guarantors’ respective existing and future unsecured senior indebtedness. Interest is payable semi-annually in arrears on February 1st and August 1st of each year. The Company assesses the convertibility of the Convertible Notes on an ongoing basis. The Convertible Notes were not convertible as of September 30, 2009.

The principal amount of the Convertible Notes is payable in cash and amounts above the principal amount, if any, will be convertible into shares of the Company’s common stock or, at the Company’s option, cash. The Convertible Notes are convertible at an initial conversion price, subject to adjustment, of $6.10 per share (approximating 163.8136 shares per one thousand dollar principal amount of the Convertible Notes). The Convertible Notes are convertible upon the occurrence of certain events, including (i) prior to February 12, 2012 during any calendar quarter after September 30, 2007, if the closing sale price per share of the Company’s common stock for each of 20 or more trading days in a period of 30 consecutive trading days ending on the last trading day of the immediately preceding calendar quarter exceeds 130% of the conversion price in effect on the last trading day of the immediately preceding calendar quarter; (ii) prior to February 12, 2012 during the five consecutive business days immediately after any five consecutive trading day period in which the average trading price for the notes on each day during such five trading-day period was equal to or less than 97% of the closing sale price of the Company’s common stock on such day multiplied by the then current conversion rate; (iii) upon the occurrence of specified corporate transactions; and (iv) at any time from, and including February 1, 2012 until the close of business on the second business day immediately preceding August 1, 2012. In addition, upon events defined as a “fundamental change” under the Convertible Notes indenture, the Company may be required to repurchase the Convertible Notes at a repurchase price in cash equal to 100% of the principal amount of the notes to be repurchased, plus any accrued and unpaid interest to, but excluding, the fundamental change repurchase date. As such, in the event the Convertible Notes become convertible, the Company would be required to classify the entire amount outstanding of the Convertible Notes as a current liability

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

in the following quarter. In the event that a significant number of the holders of the Convertible Notes were to convert their notes prior to maturity, the Company may not have enough available funds at any particular time to make the required repayments. Under these circumstances, the Company would look to WL Ross & Co. LLC (“WLR”), its banking group and other potential lenders to obtain short-term funding until such time that it could secure necessary financing on a long-term basis. The availability of any such financing would depend upon the circumstances at the time, including the terms of any such financing, and other factors. In addition, if conversion occurs in connection with certain changes in control, the Company may be required to deliver additional shares of the Company’s common stock (a “make-whole” premium) by increasing the conversion rate with respect to such notes. For a discussion of the effects of the Convertible Notes on earnings per share, see Note 8.

Effective January 1, 2009, the Company adopted ASC 470-20 (see Note 2). ASC 470-20 requires disclosure of the carrying amount of the equity component of the related convertible debt, as well as the interest expense resulting from amortization of the debt discount and interest expense recognized on the principal amount of the debt. As of September 30, 2009 and December 31, 2008, the equity component of the convertible debt was $13,517 and is included in additional paid-in capital. Interest expense resulting from amortization of the debt discount was $1,060 and $946 for the three months ended September 30, 2009 and 2008, respectively, and $3,082 and $2,750 for the nine months ended September 30, 2009 and 2008, respectively. Interest expense on the principal amount of the Convertible Notes was $5,063 for each of the three month periods ended September 30, 2009 and 2008 and $15,189 for each of the nine month periods ended September 30, 2009 and 2008.

Credit facility—The Company has a $100,000 revolving credit facility (the “Credit Facility”) which matures on June 23, 2011. A maximum of $80,000 may be used for letters of credit. In September 2009, the Company executed an amendment to the Credit Facility that affected certain debt covenants. The amendment modified the maximum permitted leverage and minimum interest coverage ratios for 2010 and thereafter. The amendment also decreased the maximum capital spending and added a minimum liquidity requirement for 2010. Pursuant to the amendment, interest on the borrowings under the Credit Facility is payable, at the Company’s option, at either the base rate plus an applicable margin of 2.75% to 3.50% or LIBOR plus an applicable margin of 3.75% to 4.50%, based on the Company’s leverage ratio. As of September 30, 2009, the Company had no borrowings outstanding and letters of credit totaling $73,551 outstanding, leaving $26,449 available for future borrowing capacity, and was in compliance with its financial covenants under the Credit Facility.

Equipment notes—The equipment notes, having various maturity dates extending to September 2014, are collateralized by mining equipment. As of September 30, 2009, the Company had amounts outstanding with terms ranging from 36 to 60 months and a weighted-average interest rate of 7.35%. At September 30, 2009, additional funds are available under the Company’s revolving equipment credit facility for terms up to 60 months with a current interest rate of 7.25%.

Capital lease and other—The Company leases certain mining equipment under a capital lease. The Company imputed interest on its capital lease using a rate of 10.44%. Additionally, the Company has an insurance policy with a coverage period of 17 months that it financed over 15 months at an interest rate of 5.42%.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Short-Term Debt

The Company finances the majority of its insurance premiums, a portion of which is included in short-term debt. As of September 30, 2009, the interest rate applicable to the note was 5.60%. As of September 30, 2009 and December 31, 2008, the Company had $269 and $4,741, respectively, outstanding related to the financing of insurance premiums.

(6) Income Taxes

The effective income tax rates for the three and nine months ended September 30, 2009 and 2008 were calculated using estimated annual effective rates based on projected earnings for the respective years, exclusive of discrete items. The effective income tax rate for the three months ended September 30, 2009 increased to 24% from 17% for the three months ended September 30, 2008. The increase was primarily a result of the effect of income tax deductions for depletion of mineral rights on increased quarterly earnings. The effective income tax rate for the nine months ended September 30, 2009 increased to 22% from 14% for the nine months ended September 30, 2008. The increase was primarily a result of the effect of income tax deductions for depletion of mineral rights on increased projected earnings, combined with an increase in other non-deductible expenses and miscellaneous items.

(7) Employee Benefits

The following table details the components of the net periodic benefit cost for postretirement benefits other than pensions for the three and nine months ended September 30, 2009 and 2008.

	Three months ended September 30,				Nine months ended September 30,
	2009		2008		2009		2008
Net periodic benefit cost:
Service cost	$	833	$	651	$	2,501	$	1,955
Interest cost		437		407		1,311		1,220
Amortization of net loss		72		107		216		322
Benefit cost	$	1,342	$	1,165	$	4,028	$	3,497

The plan is unfunded, therefore, no contributions were made by the Company for the three and nine months ended September 30, 2009 and 2008.

(8) Earnings Per Share

Basic earnings per share is computed by dividing net income available to common shareholders by the weighted-average number of common shares outstanding during the period, excluding restricted common stock subject to continuing vesting requirements. Diluted earnings per share is calculated based on the weighted-average number of common shares outstanding during the period and, when dilutive, potential common shares from the exercise of stock options, restricted common stock subject to continuing vesting requirements, restricted stock units and convertible debt, pursuant to the treasury stock method.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Reconciliations of weighted-average shares outstanding used to compute basic and diluted earnings per share for the three and nine months ended September 30, 2009 and 2008 are as follows:

	Three months ended September 30,				Nine months ended September 30,
	2009		2008		2009		2008
Net income attributable to International Coal Group, Inc.	$	18,716	$	9,324	$	32,791	$	11,181

Weighted-average common shares outstanding—basic		152,998,598		152,761,955		152,869,195		152,587,831
Incremental shares arising from:
Stock options		503,020		172,624		88,861		27,249
Restricted shares		1,529,555		91,101		1,246,964		130,394
Restricted stock units		183,695		—		84,019		—
Convertible notes		—		—		—		—
Weighted-average common shares outstanding—diluted		155,214,868		153,025,680		154,289,039		152,745,474

Earnings Per Share:
Basic	$	0.12	$	0.06	$	0.21	$	0.07
Diluted	$	0.12	$	0.06	$	0.21	$	0.07

Options to purchase 2,736,072 and 2,755,272 shares of common stock outstanding at September 30, 2009 have been excluded from the computation of diluted net income per share for the three and nine months, respectively, ended September 30, 2009 because their effect would have been anti-dilutive. Options to purchase 1,076,552 and 1,105,352 shares of common stock outstanding at September 30, 2008 have been excluded from the computation of diluted net income per share for the three and nine months, respectively, ended September 30, 2008 because their effect would have been anti-dilutive.

The principal amount of the Convertible Notes is payable in cash and amounts above the principal amount, if any, will be settled with shares of the Company’s common stock or, at the Company’s option, cash. The volume weighted-average price of the Company’s common stock for the applicable cash settlement averaging period was below the initial conversion price of $6.10 per share. Accordingly, there were no potentially dilutive shares related to the Convertible Notes at September 30, 2009 and 2008.

(9) Fair Value of Financial Instruments

The estimated fair values of the Company’s financial instruments are determined based on relevant market information. These estimates involve uncertainty and cannot be determined with precision. The following methods and assumptions were used to estimate the fair value of each class of financial instrument.

Cash and Cash Equivalents, Accounts Receivable, Accounts Payable, Short-Term Debt and Other Current Liabilities—The carrying amounts approximate the fair value due to the short maturity of these instruments.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Long-term Debt—At September 30, 2009 and December 31, 2008, the Company had $225,000 aggregate principal amount of 9.00% Convertible Notes outstanding. The fair value of the Convertible Notes was approximately $239,220 and $114,683 as of September 30, 2009 and December 31, 2008, respectively. At September 30, 2009 and December 31, 2008, the Company had $175,000 aggregate principal amount of 10.25% Senior Notes outstanding. The fair value of the Senior Notes was approximately $159,250 and $131,250 as of September 30, 2009 and December 31, 2008, respectively. The fair value of the Convertible Notes and Senior Notes were based upon their respective values in active markets.

The carrying value of the Company’s capital lease obligations and other debt approximate fair value at September 30, 2009 and December 31, 2008.

(10) Commitments and Contingencies

Guarantees and Financial Instruments with Off-balance Sheet Risk—In the normal course of business, the Company is a party to certain guarantees and financial instruments with off-balance sheet risk, such as bank letters of credit and performance or surety bonds. No liabilities related to these arrangements are reflected in the Company’s condensed consolidated balance sheets. Management does not expect any material losses to result from these guarantees or off-balance sheet financial instruments. The Company has outstanding surety bonds with third parties totaling $115,118 as of September 30, 2009 to secure reclamation and other performance commitments. As of September 30, 2009, the Company has bank letters of credit outstanding of $73,551 under its Credit Facility.

Coal Supply Agreements—Purchase price allocated to the Company’s below-market coal supply agreements (sales contracts) acquired in acquisitions accounted for as business combinations were capitalized and are being amortized on the basis of coal to be shipped over the term of each respective contract. Value was allocated to these coal supply agreements based on discounted cash flows attributable to the difference between the below-market contract price and the prevailing market price at the date of acquisition. The net book value of the Company’s below-market coal supply agreements was $30,589 and $43,888 at September 30, 2009 and December 31, 2008, respectively. Amortization income on the below-market coal supply agreements was $443 and $1,626 for the three months ended September 30, 2009 and 2008, respectively, and $5,578 and $7,081 for the nine months ended September 30, 2009 and 2008, respectively. Amortization income is included in depreciation, depletion and amortization expense. Based on the expected shipments related to the remaining below-market contracts, the Company expects to record annual amortization income in each of the next five years as reflected in the table below.

	Below-market contracts
2009 (remainder of year)	$	699
2010		3,287
2011		3,287
2012		3,287
2013		3,287

In June 2009, the Company terminated a below-market coal supply agreement and realized a $7,721 pre-tax non-cash gain. The gain is included in other revenues in the Company’s statement of operations for the nine months ended September 30, 2009.

In July 2009, one of the Company’s customers elected to exercise contractual options that provided for early termination of two related coal supply agreements. The Company received a $27,000 payment for early termination of the agreements and lost margin on pre-termination shipments. The income is included in other revenues in the Company’s statement of operations for the three and nine months ended September 30, 2009.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Legal Matters—On August 23, 2006, a survivor of the Sago mine accident, Randal McCloy, filed a complaint in the Kanawha Circuit Court in Kanawha County, West Virginia. The claims brought by Randal McCloy and his family against the Company and certain of its subsidiaries, and against W.L. Ross & Co., and Wilbur L. Ross, Jr., individually, were dismissed on February 14, 2008, after the parties reached a confidential settlement. Sixteen other complaints have been filed in Kanawha Circuit Court by the representatives of many of the miners who died in the Sago mine accident, and several of these plaintiffs have filed amended complaints to expand the group of defendants in the cases. The complaints allege various causes of action against the Company and its subsidiary, Wolf Run Mining Company, one of its shareholders, W.L. Ross & Co., and Wilbur L. Ross Jr., individually, related to the accident and seek compensatory and punitive damages. In addition, the plaintiffs also allege causes of action against other third parties, including claims against the manufacturer of Omega block seals used to seal the area where the explosion occurred and against the manufacturer of self-contained self-rescuer (“SCSR”) devices worn by the miners at the Sago mine. Some of these third parties have been dismissed from the actions upon settlement. The amended complaints add other of the Company’s subsidiaries to the cases, including ICG, Inc., ICG, LLC and Hunter Ridge Coal Company, unnamed parent, subsidiary and affiliate companies of the Company, W.L. Ross & Co., and Wilbur L. Ross Jr., and other third parties, including a provider of electrical services and a supplier of components used in the SCSR devices. The Company believes that it is appropriately insured for these and other potential claims, and has fully paid its deductible applicable to its insurance policies. In addition to the dismissal of the McCloy claim, the Company has settled and dismissed five other actions. These settlements required the release of the Company, its subsidiaries, W.L. Ross & Co., and Wilbur L. Ross, Jr. Some of the plaintiffs involved in one of the dismissed actions sought permission from the Supreme Court of Appeals of West Virginia to appeal the settlement, alleging that the settlement negotiated by the decedent’s estate should not have been approved by the trial court. The West Virginia Supreme Court of Appeals refused the petition for appeal by order entered September 3, 2009, rendering such settlement final. The Company will vigorously defend itself against the remaining complaints and any appeal of any prior settlements.

Allegheny Energy Supply (“Allegheny”), the sole customer of coal produced at the Company’s subsidiary Wolf Run Mining Company’s (“Wolf Run”) Sycamore No. 2 mine, filed a lawsuit against Wolf Run, Hunter Ridge Holdings, Inc. (“Hunter Ridge”), and the Company in state court in Allegheny County, Pennsylvania on December 28, 2006, and amended its complaint on April 23, 2007. Allegheny claims that the Company breached a coal supply contract when it declared force majeure under the contract upon idling the Sycamore No. 2 mine in the third quarter of 2006. The Sycamore No. 2 mine was idled after encountering adverse geologic conditions and abandoned gas wells that were previously unidentified and unmapped. The amended complaint also alleges that the production stoppages constitute a breach of the guarantee agreement by Hunter Ridge and breach of certain representations made upon entering into the contract in early 2005, a claim that Allegheny has since voluntarily dropped. Allegheny claims that it will incur costs in excess of $100,000 to purchase replacement coal over the life of the contract. The Company, Wolf Run and Hunter Ridge answered the amended complaint on August 13, 2007, disputing all of the remaining claims. On November 3, 2008, the Company, Wolf Run and Hunter Ridge filed an amended answer and counterclaim against the plaintiffs seeking to void the coal supply agreement due to, among other things, fraudulent inducement and conspiracy. The counterclaim alleges further that Allegheny breached a confidentiality agreement with Hunter Ridge, which prohibited the solicitation of its employees. After the coal supply agreement was executed, Allegheny hired the then-president of Anker Coal Group, Inc. (now Hunter Ridge) who engaged in negotiations on behalf of Wolf Run and Hunter Ridge. In addition to seeking a declaratory judgment that the coal supply agreement and guaranty be deemed void and unenforceable and rescission of the contracts, the counterclaim also seeks compensatory and punitive damages. On September 23, 2009, Allegheny filed a second amended complaint alleging several alternative theories of liability in its effort to extend contractual liability to the Company, which was not a party to the original contract. No new substantive claims were asserted. The Company answered the second amended complaint on October 13, 2009, denying all of the new claims. In late September 2009, Allegheny suspended deliveries from the Sycamore No. 2 mine, claiming excessive inventory at its Harrison station. The Sycamore No. 2 mine remains on idle status with no indication from the customer as to when shipments will resume.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

On December 6, 2007, the Kentucky Waterways Alliance, Inc., and The Sierra Club sued the U.S. Army Corps of Engineers (the “Corps”) in the United States District Court for the Western District of Kentucky, Louisville Division, asserting that a permit to construct five valley fills was issued unlawfully to the Company’s Hazard subsidiary for its Thunder Ridge Surface mine. The suit alleges that the Corps failed to comply with the requirements of both Section 404 of the Clean Water Act and the National Environmental Policy Act. Hazard intervened in the suit to protect the Company’s interests. The Corps suspended the Section 404 permit on December 26, 2007 in order to evaluate the issues raised by the plaintiffs. The Corps completed its evaluation on March 25, 2009, and on March 27, 2009, reinstated Hazard’s permit. Pursuant to earlier agreements with the plaintiffs in the litigation, the Company provided thirty (30) days notice to plaintiffs’ counsel of Hazard’s intent to proceed with activities authorized under the permit. After such notice, the plaintiffs agreed to amend the earlier agreement to allow Hazard partial use of the reinstated permit, including construction of an additional valley fill. Subsequently, the parties agreed to pursue resolution of the case in accordance with a scheduling order entered by the court. Pursuant to that order, the plaintiffs filed an amended complaint on July 10, 2009. The amended complaint modifies the plaintiffs’ allegations to apply to the reissued permit, rather than the original permit. The action will proceed in accordance with the scheduling order through November 2009, after which the court is expected to render a decision. If the court ultimately finds that the permit is unlawful, production could be materially affected at the Thunder Ridge Surface mine.

On January 7, 2008, Saratoga Advantage Trust (“Saratoga”) filed a class action lawsuit in the U.S. District Court for the Southern District of West Virginia against the Company and certain of its officers and directors. The complaint asserts claims under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, based on alleged false and misleading statements in the registration statements filed in connection with the Company’s November 2005 reorganization and December 2005 public offering of common stock. In addition, the complaint challenges other of the Company’s public statements regarding its operating condition and safety record. On July 6, 2009, Saratoga filed an amended complaint asserting essentially the same claims but seeking to add an individual co-plaintiff. The Company has filed a motion to dismiss the amended complaint. The Company intends to vigorously defend the action.

On July 3, 2007, Taylor Environmental Advocacy Membership, Inc. (“T.E.A.M.”) filed a petition to appeal the issuance of ICG Tygart Valley, LLC’s (“Tygart Valley”) Surface Mine Permit U-2004-06 against the West Virginia Department of Environmental Protection (the “WVDEP”) in an action before the West Virginia Surface Mine Board (the “Board”). On December 10, 2007, the Board remanded the permit to the WVDEP for revision to certain provisions related to pre-mining water monitoring and cumulative hydrologic impacts. The WVDEP issued a modification on April 1, 2008 addressing those issues. T.E.A.M. filed an appeal of the WVDEP’s approval of the permit modification on April 30, 2008. On October 7, 2008, the Board issued an order remanding the permit to the WVDEP requiring Tygart Valley to address a technical issue related to projected post-mining water quality. Tygart Valley prepared and submitted a permit modification to alleviate the Board’s concerns. The revision was approved by the WVDEP on May 27, 2009, reinstating the Tygart permit. As expected, T.E.A.M. appealed the reinstatement. A hearing has been set for December 8, 2009.

In addition, from time to time, the Company is involved in legal proceedings arising in the ordinary course of business. These proceedings include assessments of penalties for citations and orders asserted by MSHA and other regulatory agencies, none of which are expected by management to, individually or in the aggregate, have a material adverse effect on the Company. In the opinion of management, the Company has recorded adequate reserves for liabilities arising in the ordinary course and it is management’s belief there is no individual case or group of related cases pending that is likely to have a material adverse effect on the Company’s financial condition, results of operations or cash flows.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

(11) Related Party Transactions and Balances

Under an Advisory Services Agreement dated as of October 1, 2004 between the Company and WLR, WLR has agreed to provide advisory services to the Company (consisting of consulting and advisory services in connection with strategic and financial planning, investment management and administration and other matters relating to the business and operation of the Company of a type customarily provided by sponsors of U.S. private equity firms to companies in which they have substantial investments, including any consulting or advisory services which the Board of Directors reasonably requests). WLR is paid a quarterly fee of $500 and reimbursed for any reasonable out-of-pocket expenses (including expenses of third-party advisors retained by WLR). The agreement is for a period of seven years; however, it may be terminated upon the occurrence of certain events.

(12) Segment Information

The Company extracts, processes and markets steam and metallurgical coal from deep and surface mines for sale to electric utilities and industrial customers, primarily in the eastern United States. The Company operates only in the United States with mines in the Central Appalachian, Northern Appalachian and Illinois Basin regions. The Company has three reportable business segments: Central Appalachian, Northern Appalachian and Illinois Basin. The Company’s Central Appalachian operations are located in southern West Virginia, eastern Kentucky and western Virginia and include eight mining complexes. The Company’s Northern Appalachian operations are located in northern West Virginia and Maryland and include four mining complexes. The Company’s Illinois Basin operations include one mining complex. The Company also has an Ancillary category, which includes the Company’s brokered coal functions, corporate overhead, contract highwall mining services and land activities.

Reportable segment results from continuing operations for the three and nine months ended September 30, 2009 and 2008 and segment assets as of September 30, 2009 and 2008 were as follows:

Three months ended September 30, 2009:

	Central Appalachian		Northern Appalachian		Illinois Basin		Ancillary		Consolidated
Revenue	$	197,567	$	52,403	$	22,099	$	24,553	$	296,622
Adjusted EBITDA		53,654		5,795		5,170		66		64,685
Depreciation, depletion and amortization		18,171		5,100		2,221		1,504		26,996
Capital expenditures		10,995		4,700		6,953		1,045		23,693
Total assets		724,037		181,497		48,644		405,017		1,359,195

Three months ended September 30, 2008:

	Central Appalachian		Northern Appalachian		Illinois Basin		Ancillary		Consolidated
Revenue	$	207,452	$	57,589	$	21,114	$	23,044	$	309,199
Adjusted EBITDA		36,779		3,796		3,924		454		44,953
Depreciation, depletion and amortization		16,004		5,078		1,658		1,487		24,227
Capital expenditures		32,937		9,456		2,898		1,270		46,561
Total assets		744,202		186,389		35,831		401,769		1,368,191
Goodwill		—		—		—		30,237		30,237

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Revenue in the Ancillary category consists primarily of $11,054 and $12,423 relating to the Company’s brokered coal sales and $11,810 and $5,799 relating to contract highwall mining and machine sales activities for the three months ended September 30, 2009 and 2008, respectively. Capital expenditures include non-cash amounts of $14,542 and $24,935 for the three months ended September 30, 2009 and 2008, respectively. Capital expenditures do not include $3,794 and $16,673 paid during the three months ended September 30, 2009 and 2008, respectively, related to capital expenditures accrued in prior periods.

Nine months ended September 30, 2009:

	Central Appalachian		Northern Appalachian		Illinois Basin		Ancillary			Consolidated
Revenue	$	574,718	$	170,849	$	62,570	$	71,248		$	879,385
Adjusted EBITDA		130,253		21,248		11,803		(1,881	)		161,423
Depreciation, depletion and amortization		53,011		15,921		5,884		4,478			79,294
Capital expenditures		24,919		15,882		12,241		4,153			57,195
Total assets		724,037		181,497		48,644		405,017			1,359,195

Nine months ended September 30, 2008:

	Central Appalachian		Northern Appalachian		Illinois Basin		Ancillary			Consolidated
Revenue	$	536,956	$	172,923	$	60,399	$	68,731		$	839,009
Adjusted EBITDA		98,924		15,321		10,167		(9,716	)		114,696
Depreciation, depletion and amortization		47,569		12,639		5,420		5,250			70,878
Capital expenditures		71,706		31,164		3,474		4,812			111,156
Total assets		744,202		186,389		35,831		401,769			1,368,191
Goodwill		—		—		—		30,237			30,237

Revenue in the Ancillary category consists primarily of $34,494 and $39,513 relating to the Company’s brokered coal sales and $22,668 and $15,577 relating to contract highwall mining and machine sales activities for the nine months ended September 30, 2009 and 2008, respectively. Capital expenditures include non-cash amounts of $21,442 and $30,775 for the nine months ended September 30, 2009 and 2008, respectively. Capital expenditures do not include $12,942 and $14,290 paid during the nine months ended September 30, 2009 and 2008, respectively, related to capital expenditures accrued in prior periods.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

Reconciliation of net income attributable to International Coal Group, Inc. to Adjusted EBITDA for the three and nine months ended September 30, 2009 and 2008 is as follows:

	Three months ended September 30,						Nine months ended September 30,
	2009			2008			2009		2008
Net income attributable to International Coal Group, Inc.	$	18,716		$	9,324		$	32,791	$	11,181
Depreciation, depletion and amortization		26,996			24,227			79,294		70,878
Interest expense, net		13,409			9,455			39,641		30,819
Income tax expense		5,566			1,949			9,674		1,815
Noncontrolling interest		(2	)		(2	)		23		3
Adjusted EBITDA	$	64,685		$	44,953		$	161,423	$	114,696

(13) Supplementary Guarantor Information

International Coal Group, Inc. (the “Parent Company”) issued $175,000 of Senior Notes (the “Notes”) due 2014 in June 2006 and $225,000 of Convertible Senior Notes (the “Convertible Notes”) due 2012 in July 2007. The Parent Company has no independent assets or operations other than those related to the issuance, administration and repayment of the Notes and the Convertible Notes. All subsidiaries of the Parent Company (the “Guarantors”), except for a minor non-guarantor joint venture, have fully and unconditionally guaranteed the Notes and the Convertible Notes on a joint and several basis. The Guarantors are 100% owned, directly or indirectly, by the Parent Company. Accordingly, condensed consolidating financial information for the Parent Company and the Guarantors is not presented.

The Notes and the Convertible Notes are senior obligations of the Parent Company and are guaranteed on a senior basis by the Guarantors and rank senior in right of payment to the Parent Company’s and Guarantors’ future subordinated indebtedness. Amounts borrowed under the Amended Credit Facility are secured by substantially all of the assets of the Parent Company and the Guarantors on a priority basis, so the Notes and Convertible Notes are effectively subordinated to amounts borrowed under the Amended Credit Facility. Other than for corporate related purposes or interest payments required by the Notes or Convertible Notes, the Amended Credit Facility restricts the Guarantors’ abilities to make loans or pay dividends to the Parent Company in excess of $25,000 per year (or at all upon an event of default) and restricts the ability of the Parent Company to pay dividends. Therefore, all but $25,000 of the subsidiaries’ assets are restricted assets.

The Parent Company and Guarantors are subject to certain covenants under the indenture for the Notes. Under these covenants, the Parent Company and Guarantors are subject to limitations on the incurrence of additional indebtedness, payment of dividends and the incurrence of liens, however, the indenture contains no restrictions on the ability of the Guarantors to pay dividends or make payments to the Parent Company.

The obligations of the Guarantors are limited to the maximum amount permitted under bankruptcy law, the Uniform Fraudulent Conveyance Act, the Uniform Fraudulent Transfer Act or any similar Federal or state law respecting fraudulent conveyance or fraudulent transfer.

INTERNATIONAL COAL GROUP, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

September 30, 2009

(Dollars in thousands, except per share amounts)

(14) Subsequent Events

The Company has evaluated events and transactions occurring subsequent to the balance sheet date for items that should potentially be recognized or disclosed in its financial statements. The evaluation was conducted through November 6, 2009, the date of the filing of this Quarterly Report on Form 10-Q.

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Cautionary Note Regarding Forward-Looking Statements

Statements in this Quarterly Report on Form 10-Q that are not historical facts are forward-looking statements within the “safe harbor” provision of the Private Securities Litigation Reform Act of 1995 and may involve a number of risks and uncertainties. We have used the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project” and similar terms and phrases, including references to assumptions, in this report to identify forward-looking statements. These forward-looking statements are made based on expectations and beliefs concerning future events affecting us and are subject to various risks, uncertainties and factors relating to our operations and business environment, all of which are difficult to predict and many of which are beyond our control, that could cause our actual results to differ materially from those matters expressed in or implied by these forward-looking statements. The following factors are among those that may cause actual results to differ materially from our forward-looking statements:

•	market demand for coal, electricity and steel;

•	availability of qualified workers;

•	future economic or capital market conditions;

•	weather conditions or catastrophic weather-related damage;

•	our production capabilities;

•	consummation of financing, acquisition or disposition transactions and the effect thereof on our business;

•	a significant number of conversions of our Convertible Senior Notes prior to maturity;

•	our plans and objectives for future operations and expansion or consolidation;

•	our relationships with, and other conditions affecting, our customers;

•	availability and costs of key supplies or commodities such as diesel fuel, steel, explosives and tires;

•	availability and costs of capital equipment;

•	prices of fuels which compete with or impact coal usage, such as oil and natural gas;

•	timing of reductions or increases in customer coal inventories;

•	long-term coal supply arrangements;

•	reductions and/or deferrals of purchases by major customers;

•	risks in or related to coal mining operations, including risks related to third-party suppliers and carriers operating at our mines or complexes;

•	unexpected maintenance and equipment failure;

•	environmental, safety and other laws and regulations, including those directly affecting our coal mining and production, and those affecting our customers’ coal usage;

•	ability to obtain and maintain all necessary governmental permits and authorizations;

•	competition among coal and other energy producers in the United States and internationally;

•	railroad, barge, trucking and other transportation availability, performance and costs;

•	employee benefits costs and labor relations issues;

•	replacement of our reserves;

•	our assumptions concerning economically recoverable coal reserve estimates;

•	availability and costs of credit, surety bonds and letters of credit;

•	title defects or loss of leasehold interests in our properties which could result in unanticipated costs or inability to mine these properties;

•	future legislation and changes in regulations or governmental policies or changes in interpretations or enforcement thereof, including with respect to safety enhancements and environmental initiatives relating to global warming;

•	impairment of the value of our long-lived and deferred tax assets;

•	our liquidity, including the ability to adhere to financial covenants related to our borrowing arrangements, results of operations and financial condition;

•	adequacy and sufficiency of our internal controls; and

•	legal and administrative proceedings, settlements, investigations and claims and the availability of related insurance coverage.

You should keep in mind that any forward-looking statements made by us in this Quarterly Report on Form 10-Q or elsewhere speaks only as of the date on which the statements were made. New risks and uncertainties arise from time to time, and it is impossible for us to predict these events or how they may affect us or anticipated results. We have no duty to, and do not intend to, update or revise the forward-looking statements in this report after the date of this report, except as may be required by law. In light of these risks and uncertainties, you should keep in mind that any forward-looking statement made in this report might not occur. When considering these forward-looking statements, you should keep in mind the cautionary statements in this document and in our other SEC filings, including the more detailed discussion of these factors, as well as other factors that could affect our results, contained in Item 3, “Quantitative and Qualitative Disclosures About Market Risk,” as well as in the “Risks Relating to Our Business” section of Item 1A of our 2008 Annual Report on Form 10-K.

RESULTS OF CONTINUING OPERATIONS

Three months ended September 30, 2009 compared to the three months ended September 30, 2008

Revenues, coal sales revenues by reportable segment and tons sold by reportable segment

The following table depicts revenues for the three months ended September 30, 2009 and 2008 for the indicated categories:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$ or Tons			%
	(in thousands, except percentages and per ton data)
Coal sales revenues	$	246,788	$	282,250	$	(35,462	)	(13	)%
Freight and handling revenues		5,777		12,339		(6,562	)	(53	)%
Other revenues		44,057		14,610		29,447		202	%
Total revenues	$	296,622	$	309,199	$	(12,577	)	(4	)%

Tons sold		4,136		4,794		(658	)	(14	)%
Coal sales revenue per ton	$	59.67	$	58.87	$	0.80		1	%

The following table depicts coal sales revenues by reportable segment for the three months ended September 30, 2009 and 2008:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Central Appalachian	$	166,552	$	198,812	$	(32,260	)	(16	)%
Northern Appalachian		48,951		52,531		(3,580	)	(7	)%
Illinois Basin		20,230		18,530		1,700		9	%
Ancillary		11,055		12,377		(1,322	)	(11	)%
Total coal sales revenues	$	246,788	$	282,250	$	(35,462	)	(13	)%

The following table depicts tons sold by reportable segment for the three months ended September 30, 2009 and 2008:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		Tons		%
	(in thousands, except percentages)
Central Appalachian		2,463		3,022	(559	)	(18	)%
Northern Appalachian		904		918	(14	)	(2	)%
Illinois Basin		564		619	(55	)	(9	)%
Ancillary		205		235	(30	)	(13	)%
Total tons sold		4,136		4,794	(658	)	(14	)%

Coal sales revenues—Coal sales revenues are derived from sales of produced coal and brokered coal contracts. Coal sales revenues decreased for the three months ended September 30, 2009 compared to the three months ended September 30, 2008, primarily due to a 14% decrease in tons sold. Offsetting the decrease in tons sold was an increase in sales realization per ton resulting from favorable pricing on contracts entered into throughout 2008.

Central Appalachian. Coal sales revenues from our Central Appalachian segment for the three months ended September 30, 2009 decreased over the same period in 2008, primarily due to an 18% decrease in tons sold, largely driven by decreased spot market sales. Partially offsetting the decrease in tons sold was an increase in sales realization of $1.85 per ton, which was driven by higher average contract prices of our coal.

Northern Appalachian. For the three months ended September 30, 2009, our Northern Appalachian coal sales revenues decreased due to a decrease in sales realization of $3.07 per ton, principally resulting from a decrease in sales of high-priced metallurgical coal, as well as a 2% decrease in tons sold, primarily due to reduced spot market sales.

Illinois Basin. The increase in coal sales revenues from our Illinois Basin segment for the three months ended September 30, 2009 was primarily due to an increase in sales realization of $5.91 per ton, partially offset by a 9% decrease in tons sold.

Ancillary. Our Ancillary segment’s coal sales revenues are comprised of coal sold under brokered coal contracts. For the three months ended September 30, 2009, our Ancillary coal sales revenues decreased 11% primarily, due to a 13% decrease in tons sold related to the expiration of certain coal supply agreements, as well as to decreased shipments on various remaining contracts. This decrease was partially offset by increased realization of $1.28 per ton sold.

Freight and handling revenues—Freight and handling revenues represent reimbursement of freight and handling costs for certain shipments for which we initially pay the costs and are then reimbursed by the customer. Freight and handling revenues and costs decreased for the three months ended September 30, 2009 compared to the comparable period of 2008 primarily due to a decrease in sales volumes. Additionally, transportation rates and fuel surcharges have decreased as a result of decreased fuel prices.

Other revenues—The increase in other revenues for the three months ended September 30, 2009 compared to the three months ended September 30, 2008 was mainly due to a $27.0 million payment received for early termination of two related coal supply agreements and lost margin on pre-termination shipments, and to the sale of a highwall mining system during the three months ended September 30, 2009. Partially offsetting these increases were decreases in coalbed methane and contract mining revenues.

Costs and expenses

The following table depicts cost of operations for the three months ended September 30, 2009 and 2008 for the indicated categories:

	Three months ended September 30,					Increase (Decrease)
	2009		2008			$			%
	(in thousands, except percentages and per ton data)
Cost of coal sales	$	208,083	$	240,204		$	(32,121	)	(13	)%
Freight and handling costs		5,777		12,339			(6,562	)	(53	)%
Cost of other revenues		12,724		9,690			3,034		31	%
Depreciation, depletion and amortization		26,996		24,227			2,769		11	%
Selling, general and administrative expenses		5,351		8,396			(3,045	)	(36	)%
(Gain) loss on sale of assets		2		(6,383	)		6,385		*
Total costs and expenses	$	258,933	$	288,473		$	(29,540	)	(10	)%

Cost of coal sales per ton	$	50.31	$	50.10		$	0.21		0	%

* not meaningful

The following table depicts cost of coal sales by reportable segment for the three months ended September 30, 2009 and 2008:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Central Appalachian	$	140,854	$	164,193	$	(23,339	)	(14	)%
Northern Appalachian		44,491		50,494		(6,003	)	(12	)%
Illinois Basin		15,453		15,921		(468	)	(3	)%
Ancillary		7,285		9,596		(2,311	)	(24	)%
Cost of coal sales	$	208,083	$	240,204	$	(32,121	)	(13	)%

Cost of coal sales—For the three months ended September 30, 2009, our cost of coal sales decreased compared to the three months ended September 30, 2008 primarily as a result of a 14% decrease in tons sold.

Central Appalachian. Cost of coal sales from our Central Appalachian segment decreased primarily due to a 18% decrease in tons sold. Offsetting the decrease in tons sold was an increase in cost of coal sales per ton from $54.32 per ton for the three months ended September 30, 2008 to $57.19 per ton for the three months ended September 30, 2009. The increase in cost of coal sales per ton is primarily due to increases in labor and benefit costs and royalties, taxes and fees. Labor and benefit costs increased on a per ton basis as a result of lower production volumes in 2009. Royalties, taxes and fees increased on a per ton basis for the three months ended September 30, 2009 due to increased sales realization on tons sold and increased royalty rates on certain leased reserves, as well as increased property tax obligations. Partially offsetting the increase in cost per ton was a decrease in fuel, lubricants and chemicals and contract labor costs.

Northern Appalachian. Our Northern Appalachian segment cost of coal sales decreased due to a 2% decrease in tons sold coupled with a decrease in cost of coal sales per ton from $55.00 per ton for the three months ended September 30, 2008 to $49.21 per ton for the three months ended September 30, 2009. The decrease in cost per ton was primarily due to decreases in fuel, lubricants and chemicals, transportation, drilling and blasting and various other direct costs as a result of more favorable commodity pricing and production cutbacks in response to the weak market demand. Offsetting these decreases in cost per ton were increases in labor and benefit costs and contract labor costs.

Illinois Basin. For the three months ended September 30, 2009, cost of coal sales decreased due to a 9% decrease in tons sold, offset by an increase in cost of coal sales of $1.66 per ton. Cost of coal sales per ton increased as a result of an increase in labor and benefit costs. Labor and benefits increased for the three months ended September 30, 2009 due to an increase in the number of employees over the three months ended September 30, 2008.

Ancillary. Cost of coal sales from our Ancillary segment decreased for the three months ended September 30, 2009 due to a 13% decrease in tons sold and a $5.27 decrease in cost per ton.

Cost of other revenues—For the three months ended September 30, 2009, cost of other revenues increased primarily due to costs related to the sale of a highwall mining system. The increase in cost of other revenues was partially offset by decreases in repairs and maintenance costs associated with our highwall mining activities and contract buyout payments that were made in the three months ended September 30, 2008, with no comparable costs in the three months ended September 30, 2009.

Depreciation, depletion and amortization—Depreciation, depletion and amortization expense increased for the three months ended September 30, 2009, primarily due to additional capital spending throughout 2008 and into 2009 and increased depletion expense resulting from increased mining of company-owned reserves. Additionally, amortization income decreased as contracted shipments on a below-market contract was terminated in 2009. These increases were partially offset by a decrease in amortization of coalbed methane well development costs.

Selling, general and administrative expenses—Selling, general and administrative expenses for the three months ended September 30, 2009 decreased primarily due to the favorable resolution of certain legal matters and the recovery of a potential bad debt.

Gain on sale of assets—Gain on sale of assets decreased for the three months ended September 30, 2009 due to a $3.6 million gain related to the sale of a used highwall mining system during the comparable period in 2008.

Adjusted EBITDA by reportable segment

Adjusted EBITDA represents earnings before deducting interest, income taxes, depreciation, depletion, amortization and noncontrolling interest. Adjusted EBITDA is presented because it is an important supplemental measure of our performance used by our chief operating decision maker in such areas as capital investment and allocation of resources. It is considered “adjusted” as we adjust EBITDA for noncontrolling interest. Other companies in our industry may calculate Adjusted EBITDA differently than we do, limiting its usefulness as a comparative measure. Adjusted EBITDA is reconciled to its most comparable GAAP measure on page 29 of this Quarterly Report on Form 10-Q and in Note 12 to our condensed consolidated financial statements for the three months ended September 30, 2009.

The following table depicts Adjusted EBITDA by reportable segment for the three months ended September 30, 2009 and 2008:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Central Appalachian	$	53,654	$	36,779	$	16,875		46	%
Northern Appalachian		5,795		3,796		1,999		53	%
Illinois Basin		5,170		3,924		1,246		32	%
Ancillary		66		454		(388	)	(85	)%
Total Adjusted EBITDA	$	64,685	$	44,953	$	19,732		44	%

Central Appalachian. Adjusted EBITDA for the three months ended September 30, 2009 increased compared to the three months ended September 30, 2008 primarily due to a $27.0 million payment received for early termination of two related coal supply agreements and lost margin on pre-termination shipments. Partially offsetting this increase was a $1.02 per ton decrease in profit margins and 559,000 fewer tons sold.

Northern Appalachian. The increase in Adjusted EBITDA was due to increased profit margins of $2.72 per ton, offset by a decrease of approximately 14,000 tons sold.

Illinois Basin. Adjusted EBITDA increased during the three months ended September 30, 2009 resulting from an increase in sales realization of $5.91 per ton and a $1.66 increase in cost per ton, resulting in an increase in profit margins of $4.25 per ton.

Ancillary. The decrease in Adjusted EBITDA was primarily due to decreased revenue from coalbed methane wells and a decrease of approximately 30,000 tons sold related to the expiration of brokered coal contracts throughout 2008, as well as to decreased shipments on various remaining contracts. Partially offsetting these decreases were an increase in sales realization of $1.28 per ton and a $5.27 decrease in cost per ton, resulting in an increase in profit margin of $6.55 per ton.

Reconciliation of Adjusted EBITDA to net income (loss) by reportable segment

The following tables reconcile Adjusted EBITDA to net income (loss) by reportable segment for the three months ended September 30, 2009 and 2008:

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$		%
	(in thousands, except percentages)
Central Appalachian
Net income attributable to International Coal Group, Inc.	$	29,339	$	20,280	$	9,059	45	%
Depreciation, depletion and amortization		18,171		16,004		2,167	14	%
Interest expense, net		1,246		495		751	152	%
Income tax expense		4,898		—		4,898	100	%
Adjusted EBITDA	$	53,654	$	36,779	$	16,875	46	%

	Three months ended September 30,						Increase (Decrease)
	2009			2008			$			%
	(in thousands, except percentages)
Northern Appalachian
Net income (loss) attributable to International Coal Group, Inc.	$	1,078		$	(1,467	)	$	2,545		*
Depreciation, depletion and amortization		5,100			5,078			22		0	%
Interest expense, net		200			187			13		7	%
Income tax benefit		(581	)		—			(581	)	(100	)%
Noncontrolling interest		(2	)		(2	)		—		0	%
Adjusted EBITDA	$	5,795		$	3,796		$	1,999		53	%

	Three months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Illinois Basin
Net income attributable to International Coal Group, Inc.	$	2,241	$	2,204	$	37		2	%
Depreciation, depletion and amortization		2,221		1,658		563		34	%
Interest expense, net		31		62		(31	)	(50	)%
Income tax expense		677		—		677		100	%
Adjusted EBITDA	$	5,170	$	3,924	$	1,246		32	%

	Three months ended September 30,						Increase (Decrease)
	2009			2008			$			%
	(in thousands, except percentages)
Ancillary
Net loss attributable to International Coal Group, Inc.	$	(13,942	)	$	(11,693	)	$	(2,249	)	(19	)%
Depreciation, depletion and amortization		1,504			1,487			17		1	%
Interest expense, net		11,932			8,711			3,221		37	%
Income tax expense		572			1,949			(1,377	)	(71	)%
Adjusted EBITDA	$	66		$	454		$	(388	)	(85	)%

	Three months ended September 30,						Increase (Decrease)
	2009			2008			$		%
	(in thousands, except percentages)
Consolidated
Net income attributable to International Coal Group, Inc.	$	18,716		$	9,324		$	9,392	101	%
Depreciation, depletion and amortization		26,996			24,227			2,769	11	%
Interest expense, net		13,409			9,455			3,954	42	%
Income tax expense		5,566			1,949			3,617	186	%
Noncontrolling interest		(2	)		(2	)		—	0	%
Adjusted EBITDA	$	64,685		$	44,953		$	19,732	44	%

* not meaningful

RESULTS OF CONTINUING OPERATIONS

Nine months ended September 30, 2009 compared to the nine months ended September 30, 2008

Revenues, coal sales revenues by reportable segment and tons sold by reportable segment

The following table depicts revenues for the nine months ended September 30, 2009 and 2008 for the indicated categories:

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$ or Tons			%
	(in thousands, except percentages and per ton data)
Coal sales revenues	$	775,281	$	761,963	$	13,318		2	%
Freight and handling revenues		20,452		35,492		(15,040	)	(42	)%
Other revenues		83,652		41,554		42,098		101	%
Total revenues	$	879,385	$	839,009	$	40,376		5	%

Tons sold		12,996		14,502		(1,506	)	(10	)%
Coal sales revenue per ton	$	59.66	$	52.54	$	7.12		14	%

The following table depicts coal sales revenues by reportable segment for the nine months ended September 30, 2009 and 2008:

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Central Appalachian	$	526,245	$	512,537	$	13,708		3	%
Northern Appalachian		157,887		157,528		359		0	%
Illinois Basin		56,654		52,619		4,035		8	%
Ancillary		34,495		39,279		(4,784	)	(12	)%
Total coal sales revenues	$	775,281	$	761,963	$	13,318		2	%

The following table depicts tons sold by reportable segment for the nine months ended September 30, 2009 and 2008:

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		Tons		%
	(in thousands, except percentages)
Central Appalachian		7,712		8,908	(1,196	)	(13	)%
Northern Appalachian		2,959		2,969	(10	)	0	%
Illinois Basin		1,700		1,762	(62	)	(4	)%
Ancillary		625		863	(238	)	(28	)%
Total tons sold		12,996		14,502	(1,506	)	(10	)%

Coal sales revenues—Coal sales revenues are derived from sales of produced coal and brokered coal contracts. Coal sales revenues increased for the nine months ended September 30, 2009 compared to the nine months ended September 30, 2008, primarily due to a 14% increase in sales realization per ton resulting from favorable pricing on sales contracts entered into throughout 2008. Partially offsetting the impact of the improved realization per ton was a 10% decrease in tons sold, primarily a result of decreased participation in the spot market.

Central Appalachian. Coal sales revenues from our Central Appalachian segment for the nine months ended September 30, 2009 increased over the same period in 2008, primarily due to an increase in sales realization of $10.71 per ton, which was driven by higher average contract prices of our coal. Partially offsetting the increase in realization was a 13% decrease in tons sold, largely driven by decreased spot market sales.

Northern Appalachian. For the nine months ended September 30, 2009, our Northern Appalachian coal sales revenues and tons remained relatively consistent as compared to the nine months ended September 30, 2008.

Illinois Basin. The increase in coal sales revenues from our Illinois Basin segment for the nine months ended September 30, 2009 was due to an increase in sales realization of $3.46 per ton, partially offset by a 4% decrease in tons sold.

Ancillary. Our Ancillary segment’s coal sales revenues are comprised of coal sold under brokered coal contracts. For the nine months ended September 30, 2009, our Ancillary coal sales revenues decreased due to a 28% decrease in tons sold related to the expiration of certain coal supply agreements, as well as to decreased shipments on various remaining contracts. This decrease in tons sold was partially offset by an increase in sales realization of $9.70 per ton sold.

Freight and handling revenues—Freight and handling revenues represent reimbursement of freight and handling costs for certain shipments for which we initially pay the costs and are then reimbursed by the customer. Freight and handling revenues and costs decreased for the nine months ended September 30, 2009 compared to the comparable period of 2008 primarily due to a decrease in sales volumes. Additionally, transportation rates and fuel surcharges have decreased as a result of decreased fuel prices.

Other revenues—The increase in other revenues for the nine months ended September 30, 2009 compared to the nine months ended September 30, 2008 was due to $34.9 million in payments for early termination of coal supply agreements and lost margin on pre-termination shipments and a $7.7 million gain on the termination of a below-market contract, as well as to the sale of a highwall mining system during the nine months ended September 30, 2009. Partially offsetting these increases were decreases in coalbed methane revenues and sales of scrap materials.

Costs and expenses

The following table depicts cost of operations for the nine months ended September 30, 2009 and 2008 for the indicated categories:

	Nine months ended September 30,						Increase (Decrease)
	2009			2008			$			%
	(in thousands, except percentages and per ton data)
Cost of coal sales	$	647,372		$	666,598		$	(19,226	)	(3	)%
Freight and handling costs		20,452			35,492			(15,040	)	(42	)%
Cost of other revenues		28,690			27,847			843		3	%
Depreciation, depletion and amortization		79,294			70,878			8,416		12	%
Selling, general and administrative expenses		24,632			27,051			(2,419	)	(9	)%
Gain on sale of assets		(3,184	)		(32,675	)		29,491		90	%
Total costs and expenses	$	797,256		$	795,191		$	2,065		0	%

Cost of coal sales per ton	$	49.81		$	45.96		$	3.85		8	%

The following table depicts cost of coal sales by reportable segment for the nine months ended September 30, 2009 and 2008:

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Central Appalachian	$	436,827	$	443,452	$	(6,625	)	(1	)%
Northern Appalachian		141,614		147,488		(5,874	)	(4	)%
Illinois Basin		45,940		44,547		1,393		3	%
Ancillary		22,991		31,111		(8,120	)	(26	)%
Cost of coal sales	$	647,372	$	666,598	$	(19,226	)	(3	)%

Cost of coal sales—For the nine months ended September 30, 2009, our cost of coal sales decreased compared to the nine months ended September 30, 2008, primarily as a result of a 10% decrease in tons sold. Partially offsetting the decrease in tons sold was an 8% increase in cost per ton.

Central Appalachian. Our Central Appalachian segment cost of coal sales decreased primarily as a result of a 13% decrease in tons sold. The decrease in cost of coal sales due to decreased tons sold was partially offset by an increase in costs to $56.65 per ton for the nine months ended September 30, 2009 from $49.78 per ton for the nine months ended September 30, 2008. The increase in cost of coal sales per ton is primarily due to increases in labor and benefit costs and royalties, taxes and fees. Labor and benefit costs increased due to wage increases in the fourth quarter of 2008 in an effort to remain competitive in a tight labor market, lower production volumes associated with idled operations and an increase in high-dollar insurance claims over the nine months ended September 30, 2008. Royalties, taxes and fees increased on a per ton basis as a result of increased sales realization on tons sold and increased royalty rates on certain leased reserves.

Northern Appalachian. Cost of coal sales from our Northern Appalachian segment decreased for the nine months ended September 30, 2009 as a result of a decrease in costs of $1.82 per ton, while tons sold remained relatively consistent as compared to the nine months ended September 30, 2008. The decrease in cost per ton was primarily due to decreases in transportation, fuel, lubricants and chemicals and coal purchased for blending to meet customer specifications. Partially offsetting the decrease in cost per ton were increases in labor and benefits and contract labor costs.

Illinois Basin. For the nine months ended September 30, 2009, our Illinois Basin cost of coal sales increased as a result of an increase in costs of $1.74 per ton primarily due to increased labor and benefits costs. Labor and benefits increased subsequent to the third quarter of 2008 as a result of increased wages in an effort to retain skilled miners. Partially offsetting the increase in cost per ton was a 4% decrease in tons sold.

Ancillary. Cost of coal sales from our Ancillary segment decreased for the nine months ended September 30, 2009 primarily due to decreased purchased coal costs related to the expiration of certain brokered coal contracts, as well as to decreased shipments on various remaining contracts throughout 2008 and into 2009.

Cost of other revenues—For the nine months ended September 30, 2009, cost of other revenues increased primarily due to costs related to the sale of a highwall mining system. Offsetting the increase in cost of other revenues was a decrease in coalbed methane gathering fees.

Depreciation, depletion and amortization—Depreciation, depletion and amortization expense increased for the nine months ended September 30, 2009, primarily as a result of capital spending throughout 2008 and into 2009. Further impacting the increase was increased depletion expense resulting from increased mining of company-owned reserves, as well as a decrease in amortization income related to the completion or termination of shipments on certain below-market contracts. These increases were partially offset by a decrease in amortization of coalbed methane well development costs.

Selling, general and administrative expenses—Selling, general and administrative expenses for the nine months ended September 30, 2009 decreased primarily due to the favorable resolution of certain legal matters and the recovery of a potential bad debt. Partially offsetting these decreases was an increase in legal and professional fees.

Gain on sale of assets—Gain on sale of assets decreased for the nine months ended September 30, 2009. In the comparable period of 2008, we recognized a $24.6 million pre-tax gain on exchange of coal reserves with a third-party and a $3.6 million gain related to the sale of a used highwall mining system.

Adjusted EBITDA by reportable segment

Adjusted EBITDA represents earnings before deducting interest, income taxes, depreciation, depletion, amortization and noncontrolling interest. Adjusted EBITDA is presented because it is an important supplemental measure of our performance used by our chief operating decision maker in such areas as capital investment and allocation of resources. It is considered “adjusted” as we adjust EBITDA for noncontrolling interest. Other companies in our industry may calculate Adjusted EBITDA differently than we do, limiting its usefulness as a comparative measure. Adjusted EBITDA is reconciled to its most comparable GAAP measure on page 35 of this Quarterly Report on Form 10-Q and in Note 12 to our condensed consolidated financial statements for the nine months ended September 30, 2009.

The following table depicts Adjusted EBITDA by reportable segment for the nine months ended September 30, 2009 and 2008:

	Nine months ended September 30,						Increase (Decrease)
	2009			2008			$		%
	(in thousands, except percentages)
Central Appalachian	$	130,253		$	98,924		$	31,329	32	%
Northern Appalachian		21,248			15,321			5,927	39	%
Illinois Basin		11,803			10,167			1,636	16	%
Ancillary		(1,881	)		(9,716	)		7,835	81	%
Total Adjusted EBITDA	$	161,423		$	114,696		$	46,727	41	%

Central Appalachian. Adjusted EBITDA for the nine months ended September 30, 2009 increased compared to the nine months ended September 30, 2008 primarily due to $27.5 million received for early termination of coal supply agreements and lost margin on pre-termination shipments coupled with a $3.84 increase in profit margins. Partially offsetting these increases was a decrease of approximately 1.2 million tons sold.

Northern Appalachian. The increase in Adjusted EBITDA was mainly due to a combination of an increase in sales realization of $0.30 per ton and a decrease of $1.82 in cost per ton, resulting in increased profit margins of $2.12 per ton.

Illinois Basin. Adjusted EBITDA increased during the nine months ended September 30, 2009 related to an increase in sales realization of $3.46 per ton and a $1.74 increase in cost per ton, resulting in an increase in profit margins of $1.72 per ton.

Ancillary. The increase in Adjusted EBITDA was primarily due to $7.4 million received for contract settlements and an increase in sales realization of $9.70 per ton, offset by a $0.75 increase in cost per ton, resulting in an increase in profit margins of $8.95 per ton. Further impacting the increase in Adjusted EBITDA from our Ancillary segment was increased contract mining revenue, offset by decreased revenue from coalbed methane wells and a decrease of approximately 238,000 tons sold related to the expiration of brokered coal contracts throughout 2008, as well as to decreased shipments of various remaining contracts.

Reconciliation of Adjusted EBITDA to net income (loss) by reportable segment

The following tables reconcile Adjusted EBITDA to net income (loss) by reportable segment for the nine months ended September 30, 2009 and 2008:

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$		%
	(in thousands, except percentages)
Central Appalachian
Net income attributable to International Coal Group, Inc.	$	60,675	$	49,961	$	10,714	21	%
Depreciation, depletion and amortization		53,011		47,569		5,442	11	%
Interest expense, net		3,343		1,394		1,949	140	%
Income tax expense		13,224		—		13,224	100	%
Adjusted EBITDA	$	130,253	$	98,924	$	31,329	32	%

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Northern Appalachian
Net income attributable to International Coal Group, Inc.	$	4,401	$	2,194	$	2,207		101	%
Depreciation, depletion and amortization		15,921		12,639		3,282		26	%
Interest expense, net		340		485		(145	)	(30	)%
Income tax expense		563		—		563		100	%
Noncontrolling interest		23		3		20		667	%
Adjusted EBITDA	$	21,248	$	15,321	$	5,927		39	%

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$			%
	(in thousands, except percentages)
Illinois Basin
Net income attributable to International Coal Group, Inc.	$	4,505	$	4,569	$	(64	)	(1	)%
Depreciation, depletion and amortization		5,884		5,420		464		9	%
Interest expense, net		175		178		(3	)	(2	)%
Income tax expense		1,239		—		1,239		100	%
Adjusted EBITDA	$	11,803	$	10,167	$	1,636		16	%

	Nine months ended September 30,						Increase (Decrease)
	2009			2008			$			%
	(in thousands, except percentages)
Ancillary
Net loss attributable to International Coal Group, Inc.	$	(36,790	)	$	(45,543	)	$	8,753		19	%
Depreciation, depletion and amortization		4,478			5,250			(772	)	(15	)%
Interest expense, net		35,783			28,762			7,021		24	%
Income tax expense (benefit)		(5,352	)		1,815			(7,167	)	*
Adjusted EBITDA	$	(1,881	)	$	(9,716	)	$	7,835		81	%

	Nine months ended September 30,				Increase (Decrease)
	2009		2008		$		%
	(in thousands, except percentages)
Consolidated
Net income attributable to International Coal Group, Inc.	$	32,791	$	11,181	$	21,610	193	%
Depreciation, depletion and amortization		79,294		70,878		8,416	12	%
Interest expense, net		39,641		30,819		8,822	29	%
Income tax expense		9,674		1,815		7,859	433	%
Noncontrolling interest		23		3		20	667	%
Adjusted EBITDA	$	161,423	$	114,696	$	46,727	41	%

* not meaningful

Liquidity and Capital Resources

Our business is capital intensive and requires substantial capital expenditures for, among other things, purchasing and upgrading equipment used in developing and mining our coal lands, as well as remaining in compliance with environmental laws and regulations. Our principal liquidity requirements are to finance our coal production, fund capital expenditures and service our debt and reclamation obligations. We may also engage in acquisitions from time to time. Our primary sources of liquidity to meet these needs are cash on hand, cash flows from operations, borrowings under our senior credit facility and equipment financing arrangements.

We believe the principal indicators of our liquidity are our cash position and remaining availability under our credit facility. As of September 30, 2009, our available liquidity was $124.1 million, including cash of $97.7 million and $26.4 million available for borrowing under our $100.0 million senior credit facility. Total debt represented 45.1% of our total capitalization at September 30, 2009. Our total capitalization represents our current and long-term debt combined with our total stockholders’ equity.

In September 2009, we executed an amendment to our $100.0 million credit facility that affected certain debt covenants. The amendment modified the maximum permitted leverage and minimum interest coverage ratios for 2010 and thereafter. The amendment also decreased the maximum capital spending and added a minimum liquidity requirement for 2010. Management believes, based on currently available information, that we will remain in compliance with the financial covenants in our credit facility.

The unprecedented disruption in the credit markets has had a significant adverse impact on a number of financial institutions. At this time, our liquidity has not been materially impacted by the credit environment. However, CIT Group, Inc. (“CIT”), a participant in our credit facility, commenced a voluntary filing under Chapter 11 of the U.S. Bankruptcy Code on November 2, 2009. It is not certain whether CIT will honor its commitment to make loans under the credit facility or whether another lender under the credit facility might assume CIT’s commitment. Consequently, our ability to borrow under the credit facility may be adversely impacted if CIT is unable to fund its commitment and no other lender assumes its commitment. We believe this will not have a material adverse impact as we expect that commitments from other lenders under the credit facility, together with cash on hand and anticipated operating cash flows, will be sufficient to meet our near term capital requirements. We will continue to closely monitor our liquidity and the credit markets.

We currently expect our total capital expenditures will be approximately $90.0 million to $95.0 million in 2009, substantially all of which will be for equipment and infrastructure at our existing operations. Cash paid for capital expenditures was approximately $48.7 million for the nine months ended September 30, 2009. We have funded and expect to continue to fund these capital expenditures from our internal operations and equipment financing arrangements, such as our $50.0 million equipment revolving credit facility with Caterpillar Financial Services Corporation. We believe that these sources of capital will be sufficient to fund our anticipated capital expenditures through 2010. To the extent necessary, management believes it has flexibility in the timing of the cash requirements by managing the pace of capital spending. In addition, management may from time to time raise additional capital through the disposition of non-core assets or engaging in sale-leaseback transactions. The need and timing of seeking additional capital in the future will be subject to market conditions.

Approximately $18.6 million of cash paid for capital expenditures for the nine months ended September 30, 2009 was attributable to our Central Appalachian operations. This amount represents investments of approximately $4.2 million in our Beckley mining complex and $3.2 million at Hazard. We paid approximately $16.8 million at our Northern Appalachian operations in the nine months ended September 30, 2009, approximately $7.2 million of which was for investments at our Sentinel complex. Expenditures of approximately $10.2 million for our Illinois Basin operations were for development of a new mine portal and ongoing operations improvements. Approximately $3.1 million of cash paid for capital expenditures for the nine months ended September 30, 2009 was within our Ancillary segment, primarily for the upgrading of highwall mining machinery and the purchase of safety equipment.

More stringent regulatory requirements imposed upon the mining industry demand substantial capital expenditures to meet safety standards. For the nine months ended September 30, 2009, we spent $1.6 million to meet these standards and anticipate spending an additional $4.5 million for the remainder of 2009.

Cash Flows

Net cash provided by operating activities was $91.0 million for the nine months ended September 30, 2009, an increase of $46.6 million from the same period in 2008. This increase is attributable to an increase in net income of $65.8 million, after adjustment for non-cash charges, partially offset by a $19.2 million decrease due to the change in net operating assets and liabilities. Included in net income for the nine months ended September 30, 2009 is $34.9 million received for early termination of coal supply agreements and lost margin on pre-termination shipments.

For the nine months ended September 30, 2009, net cash used in investing activities was $47.0 million compared to $85.5 million for the nine months ended September 30, 2008. For the nine months ended September 30, 2009, $48.7 million of cash was paid for capital expenditures at existing mining and ancillary operations compared to $93.6 million in the same period of 2008.

Net cash used in financing activities of $10.3 million for the nine months ended September 30, 2009 was due to repayments on our short- and long-term debt of $18.2 million and finance costs of $1.2 million paid to amend our credit facility. Offsetting these repayments were borrowings of $9.1 million used to finance equipment.

Credit Facility and Long-term Debt Obligations

As of September 30, 2009 our total long-term indebtedness consisted of the following (in thousands):

	September 30, 2009
9.00% Convertible Senior Notes, due 2012, net of debt discount of $14,287	$	210,713
10.25% Senior Notes, due 2014		175,000
Equipment notes		54,566
Capital lease and other		3,942
Total		444,221
Less current portion		(17,998	)
Long-term debt	$	426,223

Other

As a regular part of our business, we review opportunities for, and engage in discussions and negotiations concerning, the acquisition of coal mining assets and interests in coal mining companies, and acquisitions of, or combinations with, coal mining companies. When we believe that these opportunities are consistent with our growth plans and our acquisition criteria, we will make bids or proposals and/or enter into letters of intent and other similar agreements, which may be binding or nonbinding, that are customarily subject to a variety of conditions and usually permit us to terminate the discussions and any related agreement if, among other things, we are not satisfied with the results of our due diligence investigation. Any acquisition opportunities we pursue could materially affect our liquidity and capital resources and may require us to incur indebtedness, seek equity capital or both. There can be no assurance that additional financing will be available on terms acceptable to us, or at all.

Additionally, we have other long-term liabilities, including, but not limited to, mine reclamation and mine closure costs, below-market coal supply agreements and “black lung” costs, and some of our subsidiaries have long-term liabilities relating to retiree health and other employee benefits.

Our ability to meet our long-term debt obligations will depend upon our future performance, which in turn, will depend upon general economic, financial and business conditions, along with competition, legislation and regulation — factors that are largely beyond our control. We believe that cash flow from operations, together with other available sources of funds, including additional borrowings under our credit facility and equipment credit facility, will be adequate at least through the third quarter of 2010 for making required payments of principal and interest on our indebtedness and for funding anticipated capital expenditures and working capital requirements. To the extent necessary, management believes it has some flexibility to manage its cash requirements by controlling the pace and timing of capital spending, utilizing availability under its credit facilities, reducing certain costs and idling high-cost operations. In addition, management may from time to time raise additional capital through the disposition of non-core assets or engage in sale-leaseback transactions. However, we cannot assure you that our operating results, cash flow and capital resources will be sufficient for repayment of our debt obligations in the future.

Our Convertible Senior Notes (the “Convertible Notes”) were not convertible as of September 30, 2009. In the event that the Convertible Notes were to become convertible and a significant number of the holders were to convert their notes prior to maturity, we may not have enough available funds at any particular time to make the required repayments. Under these circumstances, we would look to WL Ross & Co. LLC, our banking group and other potential lenders to obtain short-term funding until such time that we could secure necessary financing on a long-term basis. The availability of any such financing would depend upon the circumstances at the time, including the terms of any such financing, and other factors.

Recent Accounting Pronouncements

Fair Value Measurements—In September 2006, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Codification (“ASC”) Topic 820, Fair Value Measurements and Disclosures (“ASC 820”). ASC 820 clarified the definition of fair value, established a framework for measuring fair value and expanded the disclosures on fair value measurements. Additionally, ASC 820 permitted delayed adoption for certain non-financial assets and liabilities, which are not recognized at fair value on a recurring basis, until fiscal years, and interim periods within those fiscal years, beginning after November 15, 2008. ASC 820 demonstrated how the fair value of a financial asset is determined when the market for that financial asset is inactive, provided guidance on estimating fair value when the volume and level of activity for an asset or liability have significantly decreased in relation to normal market activity for the asset or liability and provided guidance on circumstances that may indicate that a transaction is not orderly. ASC 820 is effective for fiscal years beginning after November 15, 2007. Adoption of ASC 820 did not have a material impact on our financial position, results of operations or cash flows.

Convertible Debt—In May 2008, the FASB issued ASC Subtopic 470-20, Debt with Conversion and Other Options (“ASC 470-20”). ASC 470-20 required the liability and equity components of convertible debt instruments that may be settled in cash upon conversion to be separately accounted for in a manner that reflects the issuer’s nonconvertible debt borrowing rate. To allocate the proceeds from a convertible debt offering in this manner, a company determines the carrying amount of the liability component, which is based on the fair value of a similar liability, excluding any embedded conversion options. The resulting debt discount is amortized as additional non-cash interest expense over the period during which the debt is expected to be outstanding. ASC 470-20 was effective for financial statements for fiscal years beginning after December 15, 2008, and interim periods within those fiscal years, and has been applied retrospectively for all periods presented. We have determined our non-convertible borrowing rate would have been 11.7% at issuance. The effect of adoption of ASC 470-20 was as follows:

	December 31, 2008
	As Previously Reported			Adjustment			As Adjusted
Property, plant, equipment and mine development	$	1,068,146		$	1,151		$	1,069,297
Debt issuance costs, net		10,635			(173	)		10,462
Total assets		1,349,669			978			1,350,647

Long-term debt and capital lease		434,920			(17,369	)		417,551
Deferred tax liability		42,468			6,935			49,403
Total liabilities		854,844			(10,434	)		844,410

Additional paid-in capital		643,480			13,517			656,997
Retained deficit		(145,066	)		(2,105	)		(147,171	)
Total International Coal Group, Inc. stockholders’ equity		494,790			11,412			506,202
Total liabilities and stockholders’ equity		1,349,669			978			1,350,647

	Three months ended September 30, 2008									Nine months ended September 30, 2008
	As Previously Reported			Adjustment			As Adjusted			As Previously Reported			Adjustment			As Adjusted
Interest expense, net	$	(8,837	)	$	(618	)	$	(9,455	)	$	(29,019	)	$	(1,800	)	$	(30,819	)
Income tax expense		(2,183	)		234			(1,949	)		(2,496	)		681			(1,815	)
Net income attributable to International Coal Group, Inc.		9,708			(384	)		9,324			12,300			(1,119	)		11,181
Earnings per share:
Basic and diluted	$	0.06		$	—		$	0.06		$	0.08		$	(0.01	)	$	0.07

Business Combinations—In December 2007, the FASB issued ASC Topic 805, Business Combinations (“ASC 805”). ASC 805 will significantly change the accounting for business combinations. Under ASC 805, an acquiring entity will be required to recognize all the assets acquired and liabilities assumed in a transaction at the acquisition-date fair value with limited exceptions. ASC 805 will change the accounting treatment for certain specific acquisition-related items including: (i) expensing acquisition-related costs as incurred, (ii) valuing noncontrolling interests at fair value at the acquisition date and (iii) expensing restructuring costs associated with an acquired business. ASC 805 also includes a substantial number of new disclosure requirements. ASC 805 is to be applied to any business combination for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. Adoption of ASC 805 will impact the accounting for our future business combinations, as well as for tax uncertainties and valuation allowances from prior acquisitions.

Noncontrolling Interests—In December 2007, the FASB issued ASC Topic 810, Consolidation (“ASC 810”). ASC 810 establishes new accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. It clarifies that a noncontrolling interest in a subsidiary (minority interest) is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements and separate from the parent company’s equity. Among other requirements, this statement requires consolidated net income to be reported at amounts that include the amounts attributable to both the parent and the noncontrolling interest. It also requires disclosure, on the face of the consolidated statement of operations, of the amounts of consolidated net income attributable to the parent and to the noncontrolling interest. ASC 810 is effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Adoption of ASC 810 impacted the presentation of noncontrolling interest in our balance sheets and statements of operations and cash flows. The impact of the changes in presentation was not material.

Share-Based Payments—In June 2008, the FASB issued ASC Topic 260, Earnings Per Share (“ASC 260”). ASC 260 clarifies that all outstanding unvested share-based payment awards that contain rights to nonforfeitable dividends participate in undistributed earnings with common shareholders. Awards of this nature are considered participating securities and the two-class method of computing basic and diluted earnings per share must be applied. ASC 260 is effective for fiscal years beginning after December 15, 2008. Adoption of ASC 260 did not have a material impact on our financial position, results of operations or cash flows.

Financial Instruments—In June 2008, the FASB ratified ASC Subtopic 815-40, Contracts in Entity’s Own Equity (“ASC 815-40”). ASC 815-40 provides that an entity should use a two-step approach to evaluate whether an equity-linked financial instrument (or embedded feature) is indexed to its own stock, including evaluating the instrument’s contingent exercise and settlement provisions. It also clarifies the impact of foreign currency denominated strike prices and market-based employee stock option valuation instruments on the evaluation. ASC 815-40 is effective for fiscal years beginning after December 15, 2008. Adoption of ASC 815-40 did not have a material impact on our financial position, results of operations or cash flows.

Impairments—In April 2009, the FASB issued ASC Topic 320, Investments–Debt and Equity Securities (“ASC 320”). ASC 320 modifies the other-than-temporary impairment guidance for debt securities through increased consistency in the timing of impairment recognition and enhanced disclosures related to the credit and noncredit components of impaired debt securities that are not expected to be sold. In addition, increased disclosures are required for both debt and equity securities regarding expected cash flows, credit losses and an aging of securities with unrealized losses. ASC 320 is effective for interim and annual reporting periods that end after June 15, 2009. Adoption of ASC 320 did not impact our financial position, results of operations or cash flows.

Fair Value Instruments—In April 2009, the FASB issued ASC Topic 825, Financial Instruments (“ASC 825”). ASC 825 requires fair value disclosures for financial instruments that are not reflected in the condensed consolidated balance sheets at fair value to be disclosed on a quarterly basis, providing quantitative and qualitative information about fair value estimates. ASC 825 is effective for interim reporting periods ending after June 15, 2009. Adoption of ASC 825 did not impact our financial position, results of operations or cash flows; however, adoption did result in additional information being included in the footnotes accompanying our consolidated financial statements. See Note 9.

Subsequent Events—In May 2009, the FASB issued ASC Topic 855, Subsequent Events (“ASC 855”). ASC 855 establishes principles and requirements for events that occur after the balance sheet date, but before the issuance of the financial statements. ASC 855 requires disclosure of the date through which subsequent events have been evaluated and disclosure of certain non-recognized subsequent events. ASC 855 is effective for interim and annual periods ending after June 15, 2009. Adoption of ASC 855 did not have a material impact on our financial position, results of operations or cash flows.

Variable Interest Entities—In June 2009, the FASB issued ASC Topic 810, Consolidation (“ASC 810”) to improve financial reporting by enterprises involved with variable interest entities and to provide more relevant and reliable information to users of financial statements. ASC 810 is effective as of the first fiscal year beginning after November 15, 2009. We do not believe that adoption of ASC 810 will materially impact our financial position, results of operations or cash flows.

FASB Codification—In June 2009, the FASB issued ASC Topic 105, Generally Accepted Accounting Principles (“ASC 105”). ASC 105 makes the FASB Accounting Standards Codification the single source of authoritative U.S. accounting and reporting standards, but it does not change U.S. generally accepted accounting principles. ASC 105 is effective for interim and annual periods ending after September 15, 2009. Adoption of ASC 105 did not have a material impact on our financial condition, results of operations or cash flows.

Critical Accounting Policies, Estimates and Assumptions

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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 nine months ended September 30, 2009 are not necessarily indicative of results that can be expected for the full year. Please refer to the section entitled “Critical Accounting Policies and Estimates” of Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” in our Annual Report on Form 10-K for the year ended December 31, 2008 for a discussion of our critical accounting policies and estimates.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Market price risk. We are exposed to market price risk in the normal course of mining and selling coal. We manage this risk through the use of long-term coal supply agreements, rather than through the use of derivative instruments. As of September 30, 2009, substantially all of our 2009 projected sales are committed and priced. Any committed and unpriced projected sales are subject to future market price volatility.

Item 4.

Controls and Procedures

Disclosure Controls and Procedures

We maintain a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by us in reports that we file or submit under the Securities Exchange Act of 1934 (the “Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms. Our disclosure controls and procedures are also designed to provide reasonable assurance that information required to be disclosed in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, to allow timely decisions regarding required disclosure. As of the end of the period covered by this Quarterly Report on Form 10-Q, an evaluation of the effectiveness of our disclosure controls and procedures has been carried out under the supervision and with the participation of our management, including the Chief Executive Officer and Chief Financial Officer. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures are effective.

Changes in Internal Controls Over Financial Reporting

There have been no changes in our internal controls over financial reporting during the third quarter of fiscal 2009 that have materially affected, or are reasonably likely to materially affect, our system of internal control over financial reporting.

PART II

Item 1.

Legal Proceedings

See Note 10 – Commitments and Contingencies-Legal Matters to the condensed consolidated financial statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q relating to certain legal proceedings, which information is incorporated herein by reference.

Item 1A.

Risk Factors

Listed below are risk factors that have been revised or added to those disclosed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2008.

Judicial rulings that restrict disposal of mining spoil material could significantly increase our operating costs, discourage customers from purchasing our coal and materially harm our financial condition and operating results.

Mining in the mountainous terrain of Appalachia typically requires the use of valley fills for the disposal of excess spoil (rock and soil material) generated by construction and mining activities. In our surface mining operations, we use mountaintop removal mining wherever feasible because it allows us to recover more tons of coal per acre and facilitates the permitting of larger projects, which allows mining to continue over a longer period of time than would be the case using other mining methods. Mountaintop removal mining, along with other methods of surface mining, depends on valley fills to dispose of mining spoil material. Construction of roads, underground mine portal sites, coal processing and handling facilities and coal refuse embankments or impoundments related to both surface and underground mining also require the development of valley fills. We obtain permits to construct and operate valley fills and surface impoundments from the Army Corps of Engineers (the “Corps”) under the auspices of Section 404 of the federal Clean Water Act. Lawsuits challenging the Corps’s authority to authorize surface mining activities under Nationwide Permit 21 (“NWP21”) or under more comprehensive individual permits have been instituted by environmental groups, which also advocate for changes in federal and state laws that would prevent or further restrict the issuance of such permits. Under the provisions of a Memorandum of Understanding executed on June 11, 2009 between the Environmental Protection Agency, the Corps and the Department of the Interior, the Corps intends to suspend the use of NWP21 for surface mining activities in Appalachia while NWP21 is modified to prohibit its use to authorize discharges of dredged or fill material into waters of the United States for surface coal mining activities in the Appalachian region of the following states: Kentucky, Ohio, Pennsylvania, Tennessee, Virginia and West Virginia.

In a March 2007 decision pertaining originally to certain Section 404 permits issued to Massey Energy Company, Judge Robert C. Chambers of the U.S. District Court for the Southern District of West Virginia ruled that the Corps failed to adequately assess the impacts of surface mining on headwaters and approved mitigation that did not appropriately compensate for stream losses. Judge Chambers in June 2007 found that sediment ponds situated within a stream channel violated the prohibition against using the waters of the U.S. for waste treatment and further decided that using the reach of stream between a valley fill and the sediment pond to transport sediment-laden runoff is prohibited by the Clean Water Act. The Corps along with several intervenors appealed Judge Chambers’ decisions to the Fourth Circuit Court of Appeals, which heard oral arguments in September 2008. A three-judge panel of the Fourth Circuit on February 13, 2009 reversed, vacated and remanded Judge Chambers’ March 2007 and June 2007 decisions in their entirety, ruling that the Corps properly exercised its discretion in the permit review and approval process. On May 29, 2009 the Fourth Circuit Court of Appeals declined to rehear the case or to conduct a hearing en banc. The appellees have stated their intentions to appeal the February 13, 2009 decision to the U.S. Supreme Court.

A similar challenge to the Corps Section 404 permit process was launched by environmental groups in Kentucky in December 2007 when a lawsuit was filed in federal court against the Corps alleging that it wrongfully issued a Section 404 authorization for the expansion of ICG Hazard’s Thunder Ridge surface mine. Hazard intervened in the suit to protect our interests. The Corps suspended the Section 404 permit on December 26, 2007 in order to evaluate the issues raised by the plaintiffs. The Corps completed its evaluation on March 25, 2009, and on March 27, 2009, reinstated Hazard’s permit. Pursuant to earlier agreements with the plaintiffs in the litigation, the Company provided thirty (30) days notice to plaintiffs’ counsel of Hazard’s intent to proceed with activities authorized under the permit. After such notice, the plaintiffs agreed to amend the earlier agreement to allow Hazard partial use of the reinstated permit, including construction of an additional valley fill. Subsequently, the parties agreed to pursue resolution of the case in accordance with a scheduling order issued by the court on June 24, 2009. In accordance with that order, the plaintiffs filed an amended complaint on July 10, 2009. The amended complaint updates the plaintiffs’ allegation to challenge the reissued permit, rather than the original permit. The sequence of filings outlined in the scheduling order will continue through November 2009, after which the court is expected to render a decision. The Company currently has two subsidiaries in that jurisdiction of Kentucky that will require Section 404 permits within the next two years. If permitting requirements are substantially increased or if mining methods at issue are limited or prohibited, it could greatly lengthen the time needed to permit new reserves, significantly increase our operational costs, make it more difficult to economically recover a significant portion of our reserves and lead to a material adverse effect on our financial condition and results of operation. We may not be able to increase the price we charge for coal to cover higher production costs without reducing customer demand for our coal. See “Legal Proceedings” contained in Part II, Item 1 of this Quarterly Report on Form 10-Q.

Federal or state legislation that restricts disposal of mining spoil material or coal refuse material could eliminate certain mining methods, significantly increase our operating costs and materially harm our financial condition and operating results.

Congress and state legislatures from time to time consider proposals that would effectively prohibit the placement of materials generated by coal mining into waters of the United States, which practice is essential to surface mining in central Appalachia. A prohibition against excess spoil placement in streams would essentially eliminate surface mining in steep terrain, thus rendering much of our coal reserves unmineable. Restrictions on the placement of coal refuse material in streams or in abandoned underground coal mines could limit the life of existing coal processing operations, potentially block new coal preparation plants and at minimum significantly increase our operating costs.

Reduced coal consumption by North American electric power generators could result in lower prices for our coal, which could reduce our revenues and adversely impact our earnings and the value of our coal reserves.

Restrictions on the emission of greenhouse gases, including carbon dioxide, continue to be proposed and adopted by various legislative and regulatory bodies at federal, state and local levels of government. The intended effect of these restrictions is to discourage the combustion of fossil fuels in general and the generation of electricity by coal in particular in favor of "alternative sources" of energy which do not involve the combustion of fossil fuels. Most notably, on June 26, 2009 the U.S. House of Representatives passed The American Clean Energy and Security Act of 2009 (House Bill 2454). If enacted, this Bill would create or expand myriad federal programs designed to reduce energy produced by burning fossil fuels and increase alternative energy sources. In particular, the Bill would reduce greenhouse gas emissions via a cap and trade system for larger emitters, including coal-fired power plants. A cap would be placed on overall U.S. greenhouse gas emissions beginning in 2012 and, compared to 2005 levels, would increasingly reduce emissions by 83 percent in 2050. The economic impact of the cost of this cap on coal users would be mitigated by allocating to electric utilities and certain other industries "free allowances" which would progressively decrease over time. The imposition of such a program may result in more electric power generators shifting from coal to natural gas-fired plants or alternative energy sources. Any reduction in the amount of coal consumed by North American electric power generators could reduce the price of steam coal that we mine and sell, thereby reducing our revenues and adversely impacting our earnings and the value of our coal reserves.

We must obtain governmental permits and approvals for mining operations, which can be a costly and time-consuming process, can result in restrictions on our operations and is subject to litigation that may delay or prevent us from obtaining necessary permits.

Our operations are principally regulated under surface mining permits issued pursuant to the Surface Mining Control and Reclamation Act and state counterpart laws. Such permits are issued for terms of five years with the right of successive renewal. Separately, the Clean Water Act requires permits for operations that discharge into waters of the United States. Valley fills and refuse impoundments are authorized under permits issued by the Corps. The Environmental Protection Agency (the “EPA”) has the authority, which it has rarely exercised until recently, to object to permits issued by the Corps. While the Corps is authorized to issue permits even when the EPA has objections, the EPA does have the ability to override the Corps decision and “veto” the permits. In September 2009, the EPA announced it had identified 79 pending permit applications for Appalachian surface coal mining, under a coordination process with the Corps and the United States Department of the Interior entered into in June 2009, that the EPA believes warrant further review because of its continuing concerns about water quality and/or regulatory compliance issues. These include four of our permit applications. While the EPA has stated that its identification of these 79 permits does not constitute a determination that the mining involved cannot be permitted under the Clean Water Act and does not constitute a final recommendation from the EPA to the Corps on these projects, it is unclear how long the further review will take for our four permits or what the final outcome will be. It is also unclear what impact this process may have on our future applications for surface coal mining permits. Permitting under the Clean Water Act has been a frequent subject of litigation by environmental advocacy groups that has resulted in periodic delays in such permits issued by the Corps. Additionally, certain operations (particularly preparation plants) have permits issued pursuant to the Clean Air Act and state counterpart laws allowing and controlling the discharge of air pollutants. Regulatory authorities exercise considerable discretion in the timing of permit issuance. Requirements imposed by these authorities may be costly and time-consuming and may result in delays in, or in some instances preclude, the commencement or continuation of development or production operations. Adverse outcomes in lawsuits challenging permits or failure to comply with applicable regulations could result in the suspension, denial or revocation of required permits, which could have a material adverse impact on our financial condition, results of operations or cash flows.

Item 6.

Exhibits

10-Q EXHIBIT INDEX

3.1	Form of Second Amended and Restated Certificate of Incorporation of International Coal Group, Inc.	(A	)

3.2	Form of Second Amended and Restated By-laws of International Coal Group, Inc.	(B	)

4.1	Form of certificate of International Coal Group, Inc. common stock	(C	)

10.1	Amendment No. 1 to the Second Amended and Restated Credit Agreement, dated as of January 31, 2007, among ICG, LLC, as borrower, International Coal Group, Inc. and certain of its subsidiaries as guarantors, the lenders party thereto, J.P. Morgan Chase Securities Inc. and UBS Securities LLC, as joint lead arrangers and joint bookrunners, JPMorgan Chase Bank, N.A. and CIT Capital USA Inc., as co-syndication agents, Bank of America, N.A. and Wachovia Bank, N.A., as co-documentation agents, JPMorgan Chase Bank and Bank of America, N.A., as issuing banks, UBS Loan Finance LLC, as swingline lender, and UBS AG, Stamford Branch, as issuing bank, as administrative agent and as collateral agent for the lenders	(D	)

10.2	Second Amendment and Limited Waiver to Second Amended and Restated Credit Agreement, effective as of July 31, 2007, by and among ICG, LLC, as borrower, the guarantors party thereto, the lenders party thereto, J.P. Morgan Securities Inc. and UBS Securities LLC, as joint lead arrangers and joint bookrunners, JPMorgan Chase Bank, N.A. and CIT Capital Securities LLC, as co-syndication agents, Bank of America, N.A. and Wachovia Bank, N.A. as co-documentation agents, JPMorgan Chase Bank, N.A. as an issuing bank, UBS Loan Finance LLC, as swingline lender, and UBS AG, Stamford Branch, as an issuing bank, administrative agent and collateral agent	(E	)

10.3	Amendment No. 3 to the Second Amended and Restated Credit Agreement, dated as of February 20, 2009, among ICG, LLC, as borrower, International Coal Group, Inc. and certain of its subsidiaries as guarantors, the lenders party thereto, J.P. Morgan Chase Securities Inc. and UBS Securities LLC, as joint lead arrangers and joint bookrunners, JPMorgan Chase Bank, N.A. and CIT Capital USA Inc., as co-syndication agents, Bank of America, N.A. and Wachovia Bank, N.A., as co-documentation agents, JPMorgan Chase Bank and Bank of America, N.A., as issuing banks, UBS Loan Finance LLC, as swingline lender, and UBS AG, Stamford Branch, as issuing bank, as administrative agent and as collateral agent for the lenders	(F	)

10.4	Amendment No. 4 to the Second Amended and Restated Credit Agreement, dated as of September 28, 2009, among ICG, LLC, as borrower, International Coal Group, Inc. and certain of its subsidiaries as guarantors, the lenders party thereto, J.P. Morgan Chase Securities Inc. and UBS Securities LLC, as joint lead arrangers and joint bookrunners, JPMorgan Chase Bank, N.A. and CIT Capital USA Inc., as co-syndication agents, Bank of America, N.A. and Wachovia Bank, N.A., as co-documentation agents, JPMorgan Chase Bank and Bank of America, N.A., as issuing banks, UBS Loan Finance LLC, as swingline lender, and UBS AG, Stamford Branch, as issuing bank, as administrative agent and as collateral agent for the lenders	(G	)

31.1	Certification of the Principal Executive Officer	(H	)

31.2	Certification of the Principal Financial Officer	(H	)

32.1	Certification Pursuant to §906 of the Sarbanes Oxley Act of 2002	(H	)

(A)		Previously filed as an exhibit to Amendment No. 4 to International Coal Group, Inc.’s Registration Statement on Form S-1 (Reg. No. 333-124393), filed on October 24, 2005.

(B)		Previously filed as an exhibit to Amendment No. 5 to International Coal Group, Inc.’s Registration Statement on Form S-1 (Reg. No. 333-124393), filed on November 9, 2005.

(C)		Previously filed as an exhibit to Amendment No. 3 to International Coal Group, Inc.’s Registration Statement on Form S-1 (Reg. No. 333-124393), filed on September 28, 2005 and incorporated herein by reference.

(D)		Previously filed as an exhibit to International Coal Group, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2006 filed on March 1, 2007.

(E)		Previously filed as an exhibit to International Coal Group, Inc.’s Current Report on Form 8-K filed on July 31, 2007.

(F)		Previously filed as an exhibit to International Coal Group, Inc.’s Current Report on Form 8-K for filed on February 23, 2009.

(G)		Previously filed as an exhibit to International Coal Group, Inc.’s Current Report on Form 8-K filed on September 29, 2009.

(H)		Filed herewith.

SIGNATURES

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

INTERNATIONAL COAL GROUP, INC.

By:		/s/ Bennett K. Hatfield
Name:		Bennett K. Hatfield
Title:		President, Chief Executive Officer and Director
		(Principal Executive Officer)

By:		/s/ Bradley W. Harris
Name:		Bradley W. Harris
Title:		Senior Vice President, Chief Financial Officer and Treasurer
		(Principal Financial Officer)

Date: November 6, 2009